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0.3 0.3 0.3 0.3 --12-31 2022 29 46 0 5 38 59 14 10 0.12 0.12 0.1 0.1 0.012 0.012 0.008 0.008 20 3 20 33 15 10 20 1 35 35 FY 0001140625 0.005 0.005 0.005 0.005 0.005 0.005 1 1 35 35 20 3 20 33 15 10 20 1 FALSE <div><p style='text-align:left;margin-top:0pt;margin-bottom:0pt;line-height:11pt;' ><span style='font-family:Arial;font-size:8pt;margin-left:0pt;' >1) </span><span style='font-family:Arial;font-size:8pt;' >OCI items </span><span style='font-family:Arial;font-size:8pt;' >from equity accounted investments that may subsequently be reclassified to the Consolidated statement of income, are presented as part of OCI from equity accounted investments. OCI items that will not be reclassified to the </span><span style='font-family:Arial;font-size:8pt;' >Consolidated statements of income will be included in retained earnings. </span></p></div> <div><p style='text-align:left;margin-top:0pt;margin-bottom:0pt;line-height:10pt;' ><span style='font-family:Arial;font-size:8pt;' >The line item mainly consists of provisions, unrealised</span><span style='font-family:Arial;font-size:8pt;' > gains and losses and items of income or expense for which the cash effects are included in increase/(decrease) in working capital within operating cash flow and investing cash flows. The line item includes a fair value loss related to inventory of USD </span><span style='font-family:Arial;font-size:8pt;' >672</span><span style='font-family:Arial;font-size:8pt;' > million at 31 December 2022</span><span style='font-family:Arial;font-size:8pt;' >.</span><span style='font-family:Arial;font-size:8pt;' > </span><span style='font-family:Arial;font-size:8pt;' > </span><span style='font-family:Arial;font-size:8pt;' >Amount for 2021 includes MUSD (</span><span style='font-family:Arial;font-size:8pt;' >822</span><span style='font-family:Arial;font-size:8pt;' >) </span><span style='font-family:Arial;font-size:8pt;' >redetermination settlement</span><span style='font-family:Arial;font-size:8pt;' > for the Agbami field. </span></p></div> <div><p style='text-align:left;margin-top:0pt;margin-bottom:5pt;line-height:10pt;' ><span style='font-family:Arial;font-size:8pt;color:#000000;' >At 31 December 2022 cash and cash equivalents net overdraft was </span><span style='font-family:Arial;font-size:8pt;color:#000000;' >zero</span><span style='font-family:Arial;font-size:8pt;color:#000000;' >. At 31 December 2021 cash and cash equivalents included a net overdraf</span><span style='font-family:Arial;font-size:8pt;color:#000000;' >t of USD </span><span style='font-family:Arial;font-size:8pt;color:#000000;' >140</span><span style='font-family:Arial;font-size:8pt;color:#000000;' > million and at 31 December 2020 net overdraft were </span><span style='font-family:Arial;font-size:8pt;color:#000000;' >zero</span><span style='font-family:Arial;font-size:8pt;color:#000000;' >.</span></p></div> <div><p style='text-align:left;margin-top:0pt;margin-bottom:0pt;line-height:12pt;' ><span style='font-family:Arial;font-size:8pt;margin-left:0pt;' >Other</span><span style='font-family:Arial;font-size:8pt;' > Comprehensive Income</span><span style='font-family:Arial;font-size:8pt;' > (OCI).</span></p></div> <div><p style='text-align:left;margin-top:0pt;margin-bottom:0pt;line-height:11pt;' ><span style='font-family:Arial;font-size:8pt;' >Of which Trade receivables of USD </span><span style='font-family:Arial;font-size:8pt;' >17,334</span><span style='font-family:Arial;font-size:8pt;' > million in 2022 and USD </span><span style='font-family:Arial;font-size:8pt;' >15,237 </span><span style='font-family:Arial;font-size:8pt;' >million in 2021.</span></p></div> <div><p style='text-align:left;margin-top:0pt;margin-bottom:0pt;line-height:11pt;' ><span style='font-family:Arial;font-size:8pt;' >Includes collateral deposits of USD </span><span style='font-family:Arial;font-size:8pt;' >6,128 </span><span style='font-family:Arial;font-size:8pt;' >million for 2022 related to certain requirements set out by exchanges where Equinor is participating. 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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, DC 20549
FORM
20-F
(Mark One)
☐
REGISTRATION STATEMENT
 
PURSUANT TO SECTION 12(b) OR 12(g) OF THE SECURITIES EXCHANGE ACT OF
1934
OR
☒
 
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the fiscal year ended
December 31, 2022
OR
☐
 
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from
 
to
OR
☐
 
SHELL COMPANY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
Date of event requiring this shell company report
Commission file number
1-15200
Equinor ASA
(Exact Name of Registrant as Specified in Its Charter)
N/A
(Translation of Registrant’s Name Into English)
Norway
(Jurisdiction of Incorporation or Organization)
Forusbeen 50
,
N-4035
,
Stavanger
,
Norway
(Address of Principal Executive Offices)
Torgrim Reitan
Chief Financial Officer
Equinor ASA
Forusbeen 50
,
N-4035
Stavanger
,
Norway
Telephone No.: 011-
47
-
5199-0000
Fax No.: 011-47-
5199-0050
(Name, Telephone,
 
E-mail and/or Facsimile number and Address of Company Contact Person)
Securities registered or to be registered pursuant to Section 12(b) of the Act:
Title of Each Class
Trading Symbol(s)
Name of Each Exchange On Which
Registered
American Depositary Shares
EQNR
New York Stock Exchange
Ordinary shares, nominal value of NOK
2.50
 
each
EQNR
New York Stock Exchange
*
*Listed, not for trading, but only in connection with the registration of American Depositary Shares, pursuant to the
requirements of the Securities and Exchange Commission
Securities registered or to be registered pursuant to Section 12(g) of the Act:
 
None
Securities for which there is a reporting obligation pursuant to Section 15(d) of the Act:
 
None
 
Indicate the number of outstanding shares of each of the issuer’s classes of capital or common stock as of the close of the
period covered by the annual report.
Ordinary shares of NOK 2.50 each
3,121,942,270
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.
☒
 
Yes
 
☐
No
If this report is an annual or transition report, indicate by check mark if the registrant is not required to file reports pursuant to
Section 13 or 15(d) of the Securities Exchange Act of 1934.
☐
 
Yes
 
☒
 
No
Note – Checking the box above will not relieve any registrant required to file reports pursuant to Section 13 or 15(d) of
the Securities Exchange Act of 1934 from their obligations under those Sections.
☒
Yes
 
☐
No
Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the
Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to
file such reports), and (2) has been subject to such filing requirements for the past 90 days.
Indicate by check mark whether the registrant has submitted electronically Interactive Data File required to be submitted
pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period
that the registrant was required to submit and post such files)
☒
Yes
 
☐
No
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer,
 
or an
emerging growth company. See the definitions of “large accelerated filer,”
 
“accelerated filer,” and “emerging growth company”
in Rule 12b-2 of the Exchange Act. (Check one):
Large accelerated filer
 
☒
Accelerated filer
 
☐
Non-accelerated filer
 
☐
Emerging growth company
 
☐
 
If an emerging growth company that prepares its financial statements in accordance with U.S. GAAP, indicate
 
by check mark if
the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting
standards† provided pursuant to Section 13(a) of the Exchange Act
 
☐
† The term “new or revised financial accounting standard” refers to any update issued by the Financial Accounting Standards
Board to its Accounting Standards Codification after April 5, 2012.
 
Indicate by check mark whether the registrant has filed a report on and attestation to its management’s assessment of the
effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 762(b))
by the registered public accounting firm that prepared or issued its audit report.
☒
If securities are registered pursuant to Section 12(b) of the Act, indicate by check mark whether the financial statements of the
registrant included in the filing reflect the correction of an error to previously issued financial statements.
 
 
☐
Indicate by check mark whether any of those error corrections are restatements that required a recovery analysis of incentive
based compensation received by any of the registrant’s executive officers during the relevant recovery period pursuant to
§240.10D-1(b).
 
☐
Indicate by check mark which basis of accounting the registrant has used to prepare the financial statements included in this
filing:
U.S. GAAP
 
☐
International Financial Reporting Standards
 
as issued
by the International Accounting Standards Board
 
☒
 
Other
 
☐
If “Other” has been checked in response to the previous question, indicate by check mark which financial statement item the
registrant has elected to follow.
Item 17
 
☐
Item 18
 
☐
If this is an annual report, indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2
of the Exchange Act).
☐
Yes
 
☒
 
No
TABLE OF CONTENTS
INTRODUCTION
USE AND RECONCILIATION OF NON-GAAP FINANCIAL MEASURES
FORWARD-LOOKING STATEMENTS
PART I
ITEM 1.
 
IDENTITY OF DIRECTORS, SENIOR MANAGEMENT AND ADVISERS
A.
 
Directors and Senior Management
B.
 
Advisers
C.
 
Auditors
ITEM 2.
 
OFFER STATISTICS AND EXPECTED TIMETABLE
A.
 
Offer Statistics
B.
 
Method and Expected Timetable
ITEM 3.
 
KEY INFORMATION
A.
 
[Reserved]
B.
 
Capitalization and Indebtedness
C.
 
Reason for the Offer and Use of Proceeds
D.
 
Risk Factors
ITEM 4.
 
INFORMATION ON THE COMPANY
A.
 
History and Development of the Company
B.
 
Business Overview
C.
 
Organizational Structure
D.
 
Property, Plant and Equipment
ITEM 4A.
 
UNRESOLVED STAFF COMMENTS
ITEM 5.
 
OPERATING AND FINANCIAL REVIEW AND PROSPECTS
A.
 
Operating Results
B.
 
Liquidity and capital resources
C.
 
Research and development, Patents and Licences, etc.
D.
 
Trend information
E.
 
Critical Accounting Estimates
ITEM 6.
 
DIRECTORS, SENIOR MANAGEMENT AND EMPLOYEES
A.
 
Directors and Senior Management
B.
 
Compensation
C.
 
Board Practices
D.
 
Employees
E.
 
Share Ownership
F.
Disclosure of a registrant’s action to recover erroneously awarded compensation.
ITEM 7.
 
MAJOR SHAREHOLDERS
 
AND RELATED PARTY
 
TRANSACTIONS
A.
 
Major shareholders
B.
 
Related Party Transactions
C.
 
Interests of Experts and Counsel
ITEM 8.
 
FINANCIAL INFORMATION
A.
 
Consolidated Statements and Other Financial Information
B.
 
Significant Changes
ITEM 9.
 
THE OFFER AND LISTING
A.
 
Offer and Listing Details
B.
 
Plan of Distribution
C.
 
Markets
D.
 
Selling Shareholders
E.
 
Dilution
F.
Expenses of the Issue
ITEM 10. ADDITIONAL INFORMATION
A.
 
Share Capital
B.
 
Memorandum and Articles of Association
C.
 
Material Contracts
D.
 
Exchange controls
E.
 
Taxation
F.
Dividends and Paying Agents
G.
 
Statement by Experts
H.
 
Documents on Display
I.
 
Subsidiary Information
J.
 
Annual Report to Security Holders.
ITEM 11. QUANTITATIVE
 
AND QUALITATIVE
 
DISCLOSURES ABOUT MARKET RISK
ITEM 12. DESCRIPTION OF SECURITIES OTHER THAN EQUITY SECURITIES
A.
 
Debt Securities
B.
 
Warrants and Rights
C.
 
Other Securities
D.
 
American Depositary Shares
PART II
ITEM 13. DEFAULTS, DIVIDEND ARREARAGES AND DELINQUENCIES
ITEM 14. MATERIAL MODIFICATIONS TO THE RIGHTS OF SECURITY HOLDERS AND USE OF PROCEEDS
ITEM 15. CONTROLS AND PROCEDURES
ITEM 16. [RESERVED]
ITEM 16A. AUDIT COMMITTEE FINANCIAL EXPERT
ITEM 16B. CODE OF ETHICS
ITEM 16C. PRINCIPAL ACCOUNTANT FEES AND SERVICES
ITEM 16D. EXEMPTIONS FROM THE LISTING STANDARDS FOR AUDIT COMMITTEES
ITEM 16E. PURCHASES OF EQUITY SECURITIES BY THE ISSUER
 
AND AFFILIATED PURCHASERS
ITEM 16F. CHANGE IN REGISTRANT’S CERTIFYING ACCOUNTANT
ITEM 16G. CORPORATE GOVERNANCE
ITEM 16H. MINE SAFETY DISCLOSURE
ITEM 16I. DISCLOSURE REGARDING FOREIGN JURISDICTIONS THAT PREVENT INSPECTIONS
PART III
ITEM 17. FINANCIAL STATEMENTS
ITEM 18. FINANCIAL STATEMENTS
ITEM 19. EXHIBITS
CONSOLIDATED FINANCIAL STATEMENTS
 
 
 
INTRODUCTION
Unless otherwise indicated, all references herein to “we”, “our”, the “company”, the “group” or
 
“Equinor” are references to Equinor ASA
and its consolidated subsidiaries.
This document is our annual report on Form 20-F for the year ended 31 December 2022 (“
2022 Form 20-F
”). Reference is made to
our Norwegian Integrated Annual Report for 2022 which is attached hereto as Exhibit 15.4
 
(the “
2022 Annual Report
”) and our 2022
Remuneration Report which is attached hereto as exhibit 15.6 (the
“2022 Remuneration Report
”). Only (i) the information included in
this 2022 Form 20-F, (ii) the information in the 2022 Annual Report and the 2022 Remuneration Report that is incorporated by
reference in this 2022 Form 20-F (excluding any page references incorporated in the incorporated material
 
unless specifically noted
otherwise), and (iii) the other exhibits to this 2022 Form 20-F shall be deemed to be filed with
 
the Securities and Exchange
Commission (“
SEC
”) for any purpose, including incorporation by reference into the Registration Statement
 
on Form F-3 filed on July
10, 2020 (File No. 333-239808), and Registration Statement on Form S-8 filed on February
 
9, 2022 (File No. 333-262601) and any
other documents filed by us pursuant to the Securities Act of 1933, as amended, which
 
purport to incorporate by reference the 2022
Form 20-F. Unless otherwise indicated, references to major headings include all information under such major headings, including
subheadings, unless such reference is a reference to a subheading, in which case such reference includes
 
only the information
contained under such subheading. Any other information shall not be deemed to be so incorporated by reference.
 
In addition to the information set out below, the information set forth under the heading “Terms and abbreviations” in Section 5.9 of
Chapter 5 on pages 327 – 334 of the 2022 Annual Report is incorporated herein by reference.
The 2022 Annual Report contains references to our website (https://www
.
equinor.com).
 
Information on our website or any other
website referenced in the 2022 Annual Report is not incorporated into this document and should
 
not be considered part of this
document.
The SEC maintains an Internet website that contains reports and other information regarding
 
issuers that file electronically with the
SEC. Our filings with the SEC are available to the public through the SEC’s website at http://www.sec.gov.
The information about Equinor’s competitive position in this 2022 Form 20-F (including
 
the information in the 2022 Annual Report that
is incorporated by reference herein) is based on several sources such as investment analyst reports, independent
 
market studies, and
internal assessments of market share based on publicly available information about the financial
 
results and performance of market
players.
USE AND RECONCILIATION OF NON-GAAP FINANCIAL MEASURES
Since 2007, Equinor has been preparing its audited consolidated financial statements in accordance with
 
International Financial
Reporting Standards (IFRS) as adopted by the European Union (EU) and as issued by the International
 
Accounting Standards Board.
IFRS has been applied consistently to all periods in our audited consolidated financial statements
 
as of 31 December 2022 and 2021,
and for the three years ended 31 December 2022 included in this 2022 Form 20-F (the “Consolidated
 
financial statements”).
Non-GAAP financial measures are defined as numerical measures that either exclude
 
or include amounts that are not excluded or
included in the comparable measures calculated and presented in accordance with generally accepted
 
accounting principles: (i.e,
IFRS in the case of Equinor). The following financial measures included in this 2022 Form 20-F may
 
be considered non-GAAP
financial measures:
a)
 
Net debt to capital employed ratio, Net debt to capital employed ratio adjusted, including lease
 
liabilities and Net debt to capital
employed ratio adjusted
b)
 
Return on average capital employed (ROACE)
c)
 
Organic capital expenditures
d)
 
Free cashflow
e)
 
Adjusted earnings and adjusted earnings after tax
f)
 
Total shareholder return (TSR)
g)
 
Gross capital expenditure (gross capex)
a) Net debt to capital employed ratio
 
In Equinor’s view, net debt ratio provides a more informative picture of Equinor’s financial strength than gross interest-bearing
 
financial
debt. Three different net debt ratios are provided below; 1) net debt to capital employed ratio, 2)
 
net debt to capital employed ratio
adjusted, including lease liabilities, and 3) net debt to capital employed ratio adjusted.
The calculation is based on gross interest-bearing financial debt in the balance sheet and excludes
 
cash, cash equivalents and
current financial investments. Certain adjustments are made, e.g. collateral deposits classified
 
as cash and cash equivalents in the
Consolidated balance sheet are considered non-cash in the non-GAAP
 
calculations. The financial investments held in Equinor
Insurance AS are excluded in the non-GAAP calculations as they are deemed restricted. These two
 
adjustments increase net debt
and give a more prudent definition of the net debt to capital employed ratio than if the
 
IFRS based definition was to be used. Following
implementation of IFRS16 Equinor presents a “net debt to capital employed adjusted” excluding lease liabilities
 
from the gross
interest-bearing debt. Net interest-bearing debt adjusted for these items is included in the
 
average capital employed. The table below
reconciles the net interest-bearing debt adjusted, the capital employed and the net debt
 
to capital employed adjusted ratio with the
most directly comparable financial measure or measures calculated in accordance with IFRS.
Forward-looking net debt to capital employed ratio adjusted, including lease liabilities included in
 
this 2022 Form 20-F is not
reconcilable to its most directly comparable IFRS measure without unreasonable efforts, because the amounts
 
excluded from IFRS
measures used to determine net debt to capital employed ratio adjusted, including lease liabilities
 
cannot be predicted with reasonable
certainty.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Calculation of capital employed and net debt to capital
 
employed ratio
For the year ended 31 December
(in USD million)
2022
2021
2020
Shareholders' equity
53,988
39,010
33,873
Non-controlling interests
1
14
19
Total equity
A
53,989
39,024
33,892
Current finance debt and lease liabilities
5,617
6,386
5,777
Non-current finance debt and lease liabilities
26,551
29,854
32,338
Gross interest-bearing debt
B
32,168
36,239
38,115
Cash and cash equivalents
15,579
14,126
6,757
Current financial investments
29,876
21,246
11,865
Cash and cash equivalents and current financial investment
C
45,455
35,372
18,621
Net interest-bearing debt before adjustments
B1 = B-C
(13,288)
867
19,493
Other interest-bearing elements
 
1)
6,538
2,369
627
Net interest-bearing debt adjusted, including lease
 
liabilities
B2
(6,750)
3,236
20,121
Lease liabilities
3,668
3,562
4,405
Net interest-bearing debt adjusted
B3
(10,417)
(326)
15,716
Calculation of capital employed:
Capital employed
A+B1
40,701
39,891
53,385
Capital employed adjusted, including lease liabilities
A+B2
47,239
42,259
54,012
Capital employed adjusted
A+B3
43,571
38,697
49,608
Calculated net debt to capital employed
Net debt to capital employed
(B1)/(A+B1)
(32.6%)
2.2%
36.5%
Net debt to capital employed adjusted, including
 
lease liabilities
(B2)/(A+B2)
(14.3%)
7.7%
37.3%
Net debt to capital employed adjusted
(B3)/(A+B3)
(23.9%)
(0.8%)
31.7%
1)
Other interest-bearing elements are cash and
 
cash equivalents adjustments regarding collateral
 
deposits classified as cash and cash
 
equivalents in the Consolidated balance sheet but
 
considered as non-cash in the non-GAAP calculations
 
as well as financial investments
in Equinor Insurance AS classified as current financial
 
investments.
b) Return on average capital employed (ROACE)
ROACE is defined as adjusted earnings after tax divided by average capital employed adjusted. For
 
a reconciliation for adjusted
earnings after tax, see e) later in this section. Average capital employed adjusted at 31 December 2022 is calculated as the
 
average
of the capital employed adjusted at 31 December 2022 and at 31 December 2021 as presented in
 
the table Calculation of capital
employed and net debt to capital employed ratio section a).
Equinor uses ROACE to measure the return on capital employed adjusted, regardless of whether
 
the financing is through equity or
debt. This measure provides useful information for both the group and investors
 
about performance during the period under
evaluation. The use of ROACE should not be viewed as an alternative to income before financial
 
items, income taxes and minority
interest, or to net income, which are measures calculated in accordance with IFRS or ratios based
 
on these figures.
Forward-looking ROACE included in this 2022 Form 20-F is not reconcilable to its most directly
 
comparable IFRS measure without
unreasonable efforts, because the amounts excluded from IFRS measures used to determine ROACE
 
cannot be predicted with
reasonable certainty.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Calculated ROACE based on IFRS
31 December
(in USD million, except percentages)
2022
2021
Net income/(loss)
A
28,744
8,576
Average total equity
1
46,506
36,458
Average current finance debt and lease liabilities
6,001
6,081
Average non-current finance debt and lease liabilities
28,202
31,096
- Average cash and cash equivalents
(14,853)
(10,442)
- Average current financial investments
(25,561)
(16,555)
Average net-interest bearing debt
2
(6,210)
10,180
Average capital employed
B = 1+2
40,296
46,638
Calculated ROACE based on Net income/loss and
 
capital employed
A/B
71.3 %
18.4 %
Calculated ROACE based on Adjusted earnings after
 
tax and capital employed adjusted
 
31 December
(in USD million, except percentages)
2022
2021
Adjusted earnings after tax
A
22,691
10,042
Average capital employed adjusted
B
41,134
44,153
Calculated ROACE based on Adjusted earnings
 
after tax and capital employed adjusted
A/B
55.2%
22.7%
c) Organic capital expenditures
Capital expenditures, defined as Additions to PP&E, intangibles and equity accounted investments
 
in note 5 Segments to the
Consolidated financial statements, amounted to USD 10.0 billion in 2022.
Organic capital expenditures are capital expenditures excluding acquisitions, recognised lease assets (RoU
 
assets) and other
investments with significant different cash flow patterns. Organic capital expenditure is a measure which Equinor believes gives
relevant information about Equinor’s investments in maintenance and development
 
of the company’s assets.
In 2022, a total of USD 1.9 billion was excluded in the organic capital expenditures. Among items
 
excluded were additions of Right of
Use (RoU) assets related to leases and acquisition of Triton Power in UK, certain Statfjord licence shares and US based
 
battery
storage developer East Point Energy, resulting in organic capital expenditure of USD 8.1 billion.
In 2021, a total of USD 0.4 billion was excluded in the organic capital expenditures. Among items
 
excluded were acquisition of 100%
interest in Polish onshore renewables developer Wento and additions of Right of Use (RoU) assets related
 
to leases, resulting in
organic capital expenditure of USD 8.1 billion.
Forward-looking organic capital expenditures included in this 2022 Form 20-F are not reconcilable to the most
 
directly comparable
IFRS measure without unreasonable efforts, because the amounts excluded from such IFRS measure to determine
 
organic capital
expenditures cannot be predicted with reasonable certainty.
d) Free cash flow
Free cash flow represents, and is used by management to evaluate, cash generated from
 
operational and investing activities available
for debt servicing and distribution to shareholders. However, free cash flow is not a measure of our liquidity under IFRS and should
not be considered in isolation or as a substitute for an analysis of our results as reported in this 2022 Form
 
20-F.
 
Our definition of free
cash flow is limited and does not represent residual cash flows available for discretionary expenditures.
The following table provides a reconciliation of Free cash flow to Cash flows provided by
 
operating activities before taxes paid and
working capital items, the most directly comparable financial measure presented in accordance
 
with IFRS, as of the dates indicated:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Free cash flow
(in USD billion)
2022
2021
Cash flows provided by operating activities before taxes paid and working capital items
 
83.6
 
 
42.0
 
Taxes paid
 
(43.9)
 
(8.6)
Capital expenditures and investments
 
(8.6)
 
(8.2)
Proceeds from sale of assets and businesses
 
1.0
 
 
1.9
 
Free cash flow before capital distribution
 
32.1
 
 
27.1
 
Dividend paid
 
(5.4)
 
(1.8)
Share buy-back
 
(3.3)
 
(0.3)
Free cash flow
 
23.4
 
 
25.0
 
e) Adjusted earnings and adjusted earnings after tax
Management considers adjusted earnings and adjusted earnings after tax together with other non-GAAP
 
financial measures as
defined below, to provide an indication of the underlying operational and financial performance in the period (excluding financing) by
adjusting by items that are not well correlated to Equinor’s operating performance, and therefore
 
better facilitate comparisons between
periods.
Adjusted earnings
are based on net operating income/(loss) and adjusts for certain items affecting the income for the period in
 
order
to separate out effects that management considers may not be well correlated to Equinor’s underlying
 
operational performance in the
individual reporting period. Management considers adjusted earnings to be a supplemental
 
measure to Equinor’s IFRS measures,
which provides an indication of Equinor’s underlying operational performance in the
 
period and facilitates an alternative understanding
of operational trends between the periods. Adjusted earnings include adjusted revenues and other income, adjusted
 
purchases,
adjusted operating expenses and selling, general and administrative expenses, adjusted depreciation expenses
 
and adjusted
exploration expenses.
 
Adjusted earnings adjusts for the following items:
●
Changes in fair value of derivatives:
 
Certain gas contracts are, due to pricing or delivery conditions, deemed to contain
embedded derivatives, required to be carried at fair value. Also, certain transactions related to
 
historical divestments include
contingent consideration, are carried at fair value. The accounting impacts of changes in fair
 
value of the aforementioned are
excluded from adjusted earnings. In addition, adjustments are also made for changes in the unrealised
 
fair value of derivatives
related to some natural gas trading contracts. Due to the nature of these gas sales contracts, these
 
are classified as financial
derivatives to be measured at fair value at the balance sheet date. Unrealised gains and losses
 
on these contracts reflect the
value of the difference between current market gas prices and the actual prices to be realised under the gas sales
 
contracts. Only
realised gains and losses on these contracts are reflected in adjusted earnings. This presentation best reflects
 
the underlying
performance of the business as it replaces the effect of temporary timing differences associated with the re-measurements of the
derivatives to fair value at the balance sheet date with actual realised gains and losses for the
 
period
●
Periodisation of inventory hedging effect:
Commercial storage is hedged in the paper market and is accounted for using the
lower of cost or market price. If market prices increase above cost price, the inventory will
 
not reflect this increase in value. There
will be a loss on the derivative hedging the inventory since the derivatives always reflect changes in the market
 
price. An
adjustment is made to reflect the unrealised market increase of the commercial storage. As
 
a result, loss on derivatives is
matched by a similar adjustment for the exposure being managed. If market prices decrease below
 
cost price, the write-down of
the inventory and the derivative effect in the IFRS income statement will offset each other and no adjustment is made
●
Over/underlift
: Over/underlift is accounted for using the sales method and therefore revenues were reflected
 
in the period the
product was sold rather than in the period it was produced. The over/underlift position
 
depended on a number of factors related to
our lifting programme and the way it corresponded to our entitlement share
 
of production. The effect on income for the period is
therefore adjusted, to show estimated revenues and associated costs based upon the production
 
for the period to reflect
operational performance and comparability with peers.
●
The
operational storage
is not hedged and is not part of the trading portfolio. Cost of goods sold is measured
 
based on the
FIFO (first-in, first-out) method, and includes realised gains or losses that arise due to
 
changes in market prices. These gains or
losses will fluctuate from one period to another and are not considered part of the underlying
 
operations for the period
●
Impairment and reversal of impairment
are excluded from adjusted earnings since they affect the economics of an asset for
the lifetime of that asset, not only the period in which it is impaired or the
 
impairment is reversed. Impairment and reversal of
impairment can impact both the exploration expenses and the depreciation, amortisation and net impairments line
 
items
●
Gain or loss from sales of assets
is eliminated from the measure since the gain or loss does not give an indication
 
of future
performance or periodic performance; such a gain or loss is related to the cumulative value creation from the
 
time the asset is
acquired until it is sold
●
Eliminations (Internal unrealised profit on inventories:):
Volumes derived from equity oil inventory will vary depending on
several factors and inventory strategies, i.e. level of crude oil in inventory, equity oil used in the refining process and level of in-
transit cargoes. Internal profit related to volumes sold between entities within the group, and still
 
in inventory at period end, is
eliminated according to IFRS (write down to production cost). The proportion of realised versus unrealised gain will
 
fluctuate from
one period to another due to inventory strategies and consequently impact net
 
operating income/(loss). Write-down to production
cost is not assessed to be a part of the underlying operational performance, and elimination
 
of internal profit related to equity
volumes is excluded in adjusted earnings
●
Other items of income and expense
are adjusted when the impacts on income in the period are not reflective of Equinor’s
underlying operational performance in the reporting period. Such items may be unusual
 
or infrequent transactions but they may
also include transactions that are significant which would not necessarily qualify as either
 
unusual or infrequent. However, other
items adjusted do not constitute normal, recurring income and operating expenses for the company. Other items are carefully
assessed and can include transactions such as provisions related to reorganisation, early retirement,
 
etc.
●
Change in accounting policy
 
are adjusted when the impacts on income in the period are unusual or infrequent,
 
and not
reflective of Equinor’s underlying operational performance in the reporting
 
period
Adjusted earnings after tax
– equals the sum of net operating income/(loss) less income tax in reporting segments and adjustments
to operating income taking the applicable marginal tax into consideration. Adjusted earnings after
 
tax excludes net financial items and
the associated tax effects on net financial items. It is based on adjusted earnings less the tax effects on all elements
 
included in
adjusted earnings (or calculated tax on operating income and on each of the adjusting items
 
using an estimated marginal tax rate). In
addition, tax effect related to tax exposure items not related to the individual reporting period is excluded from
 
adjusted earnings after
tax. Management considers adjusted earnings after tax, which reflects a normalised tax charge
 
associated with its operational
performance excluding the impact of financing, to be a supplemental measure to Equinor’s
 
net income. Certain net USD denominated
financial positions are held by group companies that have a USD functional currency that is different from the currency
 
in which the
taxable income is measured. As currency exchange rates change between periods, the basis
 
for measuring net financial items for
IFRS will change disproportionally with taxable income which includes exchange gains and losses
 
from translating the net USD
denominated financial positions into the currency of the applicable tax return. Therefore, the
 
effective tax rate may be significantly
higher or lower than the statutory tax rate for any given period. Adjusted taxes included
 
in adjusted earnings after tax should not be
considered indicative of the amount of current or total tax expense (or taxes payable)
 
for the period.
Adjusted earnings and adjusted earnings after tax should be considered additional measures rather
 
than substitutes for net operating
income/(loss) and net income/(loss), which are the most directly comparable IFRS measures. There
 
are material limitations
associated with the use of adjusted earnings and adjusted earnings after tax compared with the
 
IFRS measures as such non-GAAP
measures do not include all the items of revenues/gains or expenses/losses of Equinor that
 
are needed to evaluate its profitability on
an overall basis. Adjusted earnings and adjusted earnings after tax are only intended to be
 
indicative of the underlying developments
in trends of our on-going operations for the production, manufacturing and marketing of our
 
products and exclude pre-and post-tax
impacts of net financial items. Equinor reflects such underlying development in our operations by eliminating
 
the effects of certain
items that may not be directly associated with the period's operations or financing. However, for that reason, adjusted earnings and
adjusted earnings after tax are not complete measures of profitability. These measures should therefore not be used in isolation.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Items impacting net operating income/(loss) in the
full year of 2022
Equinor
group
E&P Norway
E&P
Internationa
l
E&P USA
MMP
REN
Other
(in USD million)
Total revenues
 
and other income
 
150,806
 
 
75,930
 
 
7,431
 
 
5,523
 
 
148,105
 
 
185
 
 
(86,367)
Adjusting items
 
(896)
 
(487)
 
185
 
 
-
 
 
(506)
 
(110)
 
22
 
Changes in fair value of derivatives
 
(207)
 
(263)
 
205
 
 
-
 
 
(149)
 
-
 
 
-
 
Periodisation of inventory hedging effect
 
(349)
 
-
 
 
-
 
 
-
 
 
(349)
 
-
 
 
-
 
Impairment from associated companies
 
1
 
 
-
 
 
-
 
 
-
 
 
-
 
 
1
 
 
-
 
Over-/underlift
 
510
 
 
507
 
 
3
 
 
-
 
 
-
 
 
-
 
 
-
 
Other adjustments
1)
 
(0)
 
-
 
 
(22)
 
-
 
 
-
 
 
-
 
 
22
 
Gain/loss on sale of assets
 
(850)
 
(731)
 
-
 
 
-
 
 
(9)
 
(111)
 
(0)
Adjusted total revenues and other income
 
149,910
 
 
75,443
 
 
7,616
 
 
5,523
 
 
147,599
 
 
75
 
 
(86,345)
Purchases [net of inventory variation]
 
(53,806)
 
0
 
 
(116)
 
(0)
 
(139,916)
 
-
 
 
86,227
 
Adjusting items
 
(610)
 
-
 
 
-
 
 
-
 
 
(33)
 
-
 
 
(577)
Operational storage effects
 
(33)
 
-
 
 
-
 
 
-
 
 
(33)
 
-
 
 
-
 
Eliminations
 
(577)
 
-
 
 
-
 
 
-
 
 
-
 
 
-
 
 
(577)
Adjusted purchases [net of inventory variation]
 
(54,415)
 
0
 
 
(116)
 
(0)
 
(139,949)
 
-
 
 
85,650
 
Operating and administrative expenses
 
 
(10,594)
 
(3,782)
 
(1,698)
 
(938)
 
(4,591)
 
(265)
 
681
 
Adjusting items
 
64
 
 
(54)
 
22
 
 
6
 
 
75
 
 
10
 
 
5
 
Over-/underlift
 
(41)
 
(54)
 
13
 
 
-
 
 
-
 
 
-
 
 
-
 
Other adjustments
 
7
 
 
-
 
 
2
 
 
-
 
 
-
 
 
-
 
 
5
 
Gain/loss on sale of assets
 
23
 
 
-
 
 
7
 
 
6
 
 
-
 
 
10
 
 
-
 
Provisions
 
75
 
 
-
 
 
-
 
 
-
 
 
75
 
 
-
 
 
-
 
Adjusted operating and administrative expenses
 
 
(10,530)
 
(3,836)
 
(1,675)
 
(933)
 
(4,516)
 
(255)
 
686
 
Depreciation, amortisation and net impairments
 
(6,391)
 
(4,167)
 
(1,731)
 
(361)
 
14
 
 
(4)
 
(142)
Adjusting items
 
(2,488)
 
(819)
 
286
 
 
(1,060)
 
(895)
 
-
 
 
-
 
Impairment
 
1,111
 
 
3
 
 
1,033
 
 
-
 
 
75
 
 
-
 
 
-
 
Reversal of impairment
 
(3,598)
 
(821)
 
(747)
 
(1,060)
 
(970)
 
-
 
 
-
 
Adjusted depreciation, amortisation and net
impairments
 
(8,879)
 
(4,986)
 
(1,445)
 
(1,422)
 
(881)
 
(4)
 
(142)
Exploration expenses
 
(1,205)
 
(366)
 
(638)
 
(201)
 
-
 
 
-
 
 
-
 
Adjusting items
 
59
 
 
4
 
 
65
 
 
(11)
 
-
 
 
-
 
 
-
 
Impairment
 
85
 
 
4
 
 
65
 
 
15
 
 
-
 
 
-
 
 
-
 
Reversal of impairment
 
(26)
 
-
 
 
-
 
 
(26)
 
-
 
 
-
 
 
-
 
Adjusted exploration expenses
 
(1,146)
 
(361)
 
(573)
 
(212)
 
-
 
 
-
 
 
-
 
Net operating income/(loss)
 
78,811
 
 
67,614
 
 
3,248
 
 
4,022
 
 
3,612
 
 
(84)
 
399
 
Sum of adjusting items
 
(3,871)
 
(1,355)
 
559
 
 
(1,065)
 
(1,360)
 
(100)
 
(550)
Adjusted earnings/(loss)
 
74,940
 
 
66,260
 
 
3,806
 
 
2,957
 
 
2,253
 
 
(184)
 
(151)
Tax on adjusted
 
earnings
 
(52,250)
 
(51,373)
 
(1,248)
 
(79)
 
474
 
 
14
 
 
(38)
Adjusted earnings/(loss) after tax
 
22,691
 
 
14,887
 
 
2,558
 
 
2,878
 
 
2,727
 
 
(170)
 
(189)
1) The adjustment in E&P International and Other is related
 
to recirculation of currency effects resulting from
 
exit of equity accounted companies.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Items impacting net operating income/(loss) in the
full year of 2021
Equinor
group
E&P Norway
E&P
Internationa
l
E&P USA
MMP
REN
Other
(in USD million)
Total revenues
 
and other income
1)
 
90,924
 
 
39,386
 
 
5,566
 
 
4,149
 
 
87,393
 
 
1,411
 
 
(46,980)
Adjusting Items
 
(1,836)
 
(339)
 
43
 
 
-
 
 
(155)
 
(1,381)
 
(4)
Changes in fair value of derivatives
 
(146)
 
(145)
 
36
 
 
-
 
 
(37)
 
-
 
 
-
 
Periodisation of inventory hedging effect
 
49
 
 
-
 
 
-
 
 
-
 
 
49
 
 
-
 
 
-
 
Impairment from associated companies
 
4
 
 
-
 
 
-
 
 
-
 
 
-
 
 
4
 
 
-
 
Over-/underlift
 
(125)
 
(194)
 
69
 
 
-
 
 
-
 
 
-
 
 
-
 
Gain/loss on sale of assets
 
(1,561)
 
-
 
 
(5)
 
-
 
 
(167)
 
(1,385)
 
(4)
Provisions
 
(57)
 
-
 
 
(57)
 
-
 
 
-
 
 
-
 
 
-
 
Adjusted total revenues and other income
1)
 
89,088
 
 
39,047
 
 
5,609
 
 
4,149
 
 
87,238
 
 
30
 
 
(46,984)
Purchases [net of inventory variation]
 
(35,160)
 
(0)
 
(58)
 
(0)
 
(80,873)
 
(0)
 
45,771
 
Adjusting Items
 
230
 
 
-
 
 
-
 
 
-
 
 
(231)
 
-
 
 
461
 
Operational storage effects
 
(231)
 
-
 
 
-
 
 
-
 
 
(231)
 
-
 
 
-
 
Eliminations
 
461
 
 
-
 
 
-
 
 
-
 
 
-
 
 
-
 
 
461
 
Adjusted purchases [net of inventory variation]
 
(34,930)
 
(0)
 
(58)
 
(0)
 
(81,104)
 
(0)
 
46,232
 
Operating and administrative expenses
1)
 
(9,378)
 
(3,652)
 
(1,406)
 
(1,074)
 
(3,753)
 
(163)
 
670
 
Adjusting Items
 
(11)
 
62
 
 
(32)
 
35
 
 
(87)
 
-
 
 
12
 
Over-/underlift
 
23
 
 
55
 
 
(32)
 
-
 
 
-
 
 
-
 
 
-
 
Other adjustments
2)
 
(43)
 
7
 
 
-
 
 
-
 
 
(50)
 
-
 
 
-
 
Gain/loss on sale of assets
 
47
 
 
-
 
 
-
 
 
35
 
 
-
 
 
-
 
 
12
 
Provisions
 
(37)
 
-
 
 
-
 
 
-
 
 
(37)
 
-
 
 
-
 
Adjusted operating and administrative expenses
1)
 
(9,389)
 
(3,590)
 
(1,438)
 
(1,039)
 
(3,841)
 
(163)
 
682
 
Depreciation, amortisation and net impairments
1)
 
(11,719)
 
(4,900)
 
(3,321)
 
(1,734)
 
(1,604)
 
(3)
 
(156)
Adjusting Items
 
1,288
 
 
(1,102)
 
1,587
 
 
69
 
 
735
 
 
-
 
 
-
 
Impairment
 
2,963
 
 
276
 
 
1,836
 
 
116
 
 
735
 
 
-
 
 
-
 
Reversal of impairment
 
(1,675)
 
(1,379)
 
(250)
 
(47)
 
-
 
 
-
 
 
-
 
Adjusted depreciation, amortisation and net
impairments
1)
 
(10,431)
 
(6,002)
 
(1,734)
 
(1,665)
 
(869)
 
(3)
 
(156)
Exploration expenses
 
(1,004)
 
(363)
 
(451)
 
(190)
 
-
 
 
-
 
 
0
 
Adjusting Items
 
152
 
 
7
 
 
101
 
 
44
 
 
-
 
 
-
 
 
-
 
Impairment
 
175
 
 
7
 
 
101
 
 
66
 
 
-
 
 
-
 
 
-
 
Reversal of impairment
 
(22)
 
-
 
 
-
 
 
(22)
 
-
 
 
-
 
 
-
 
Adjusted exploration expenses
 
(852)
 
(356)
 
(350)
 
(146)
 
-
 
 
-
 
 
0
 
Net operating income/(loss)
1)
 
33,663
 
 
30,471
 
 
329
 
 
1,150
 
 
1,163
 
 
1,245
 
 
(695)
Sum of adjusting items
 
(177)
 
(1,372)
 
1,698
 
 
147
 
 
262
 
 
(1,381)
 
469
 
Adjusted earnings/(loss)
1)
 
33,486
 
 
29,099
 
 
2,028
 
 
1,297
 
 
1,424
 
 
(136)
 
(227)
Tax on adjusted
 
earnings
 
(23,445)
 
(21,825)
 
(670)
 
(16)
 
(998)
 
23
 
 
40
 
Adjusted earnings/(loss) after tax
1)
 
10,042
 
 
7,274
 
 
1,358
 
 
1,281
 
 
426
 
 
(112)
 
(187)
1) E&P Norway, E&P International,
 
MMP and Other segments are restated due to implementation
 
of IFRS 16 in the segments
2) The adjustment for MMP is related to an insurance settlement.
f) Total
 
shareholder return (TSR)
Total shareholder return (TSR) is the sum of a share’s price growth and dividends for the same period, divided by the share price at
beginning of period.
g) Gross capital expenditure (gross capex)
Capital expenditures, defined as Additions to PP&E, intangibles and equity accounted investments,
 
amounted to USD 10.0 billion in
2022 and USD 8.5 billion in 2021 (as referenced in note 5 Segments to the Consolidated
 
financial statements).
Gross capital expenditures are capital expenditures that are adjusted to exclude additions of Right
 
of use assets related to leases (as
referenced in note 12, Property, plant and equipment, to the consolidated financial statements) and to include Equinor’s proportionate
share of capital expenditures in equity accounted investments not included in additions to equity
 
accounted investments, within the
REN segment for 2021 and 2022. The calculation of gross capital expenditures excludes additions
 
to right of use assets related to
leases, as management believes that this better reflects the Group's investments in the
 
business to drive growth.
In 2022, a net total adjustment of USD 0.4 billion was excluded, resulting in gross capital
 
expenditures of USD 9.6 billion. In 2021, a
net total adjustment of USD 0.3 billion was included, resulting in gross capital expenditures of USD
 
8.8 billion.
Forward-looking gross capital expenditures included in this 2022 Form 20-F are not reconcilable to the
 
most directly comparable IFRS
measure without unreasonable efforts, because the amounts excluded from such IFRS measure to determine gross
 
capital
expenditures cannot be predicted with reasonable certainty.
FORWARD-LOOKING STATEMENTS
This 2022 Form 20-F (including information incorporated
 
herein from the 2022 Annual Report) contains
 
certain forward-looking statements that
involve risks and uncertainties, in particular in the
 
sections incorporated by reference in Item 4
 
of this 2022 Form 20-F. In some cases, we use
words such as "aim", "ambition", "anticipate", "believe",
 
"continue", "could", "estimate", "expect", "intend", "likely",
 
"objective", "outlook", "may",
"plan", "schedule", "seek", "should", "strategy", "target",
 
"will", "goal" and similar expressions to identify
 
forward-looking statements. All
statements other than statements of historical fact,
 
including: the commitment to develop as a broad
 
energy company and ambition to be a
leading company in the energy transition; ambition
 
to reach net zero by 2050 and expectations
 
regarding progress on our energy transition
plan and just transition plan; our ambitions regarding
 
reduction in operated emissions and net
 
carbon intensity and allocation of gross capex*
to renewables and low carbon solutions; our ambitions
 
to decarbonise and maintain value in oil and gas,
 
industrialise and upscale offshore
wind, industrialise and commercialise carbon capture
 
and storage and upscale and develop new
 
value chains in hydrogen; ambition to attain a
leadership position in the European CCS market; aims,
 
expectations and plans for renewables production
 
capacity and power generation,
investments in renewables and low-carbon solutions
 
and the balance between oil and renewables
 
production; our expectations with respect to
net carbon intensity, operated emissions, carbon and methane intensity and
 
flaring reductions; our internal carbon price
 
and other financial
metrics for investment decisions; break-even considerations
 
and targets; aims and expectations regarding
 
Equinor’s resilience across different
climate scenarios; future levels of, and expected value
 
creation from, oil and gas production, scale and
 
composition of the oil and gas portfolio,
and development of CCS and hydrogen businesses;
 
use of compensation
 
and offset mechanisms and high-quality carbon sinks; plans
 
to
develop fields; our intention to optimise and mature
 
our portfolio; future worldwide economic
 
trends, market outlook and future economic
projections and assumptions, including commodity
 
price assumptions; expectations and plans regarding
 
capital expenditures; future financial
performance, including cash flow, liquidity and return on average capital
 
employed (ROACE)*; expectations regarding
 
cash flow and returns
from our oil and gas portfolio and renewable
 
projects; organic capital expenditures through 2026;
 
expectations and estimates regarding
production and execution of projects; the ambition
 
to keep unit of production cost in the top quartile
 
of our peer group; scheduled maintenance
activity and the effects thereof on equity production; business
 
strategy and competitive position; sales, trading
 
and market strategies; research
and development initiatives and strategy, including ambitions regarding
 
allocation of research and development capital
 
towards renewables
and low carbon-solutions; expectations related to production
 
levels, unit production cost, investment, exploration
 
activities, discoveries and
development in connection with our ongoing transactions
 
and projects; our ambitions, expectations and
 
plans regarding diversity and inclusion
and employee training; plans and expectations regarding
 
completion and results of acquisitions, disposals and
 
other contractual arrangements
and delivery commitments; plans, ambitions and expectations
 
regarding recovery factors and levels, future margins and
 
future levels or
development of capacity, reserves or resources; planned turnarounds and other
 
maintenance activity; expectations regarding oil and
 
gas
volume growth, including for volumes lifted and sold
 
to equal entitlement production; estimates related
 
to production and development,
forecasts, reporting levels and dates; operational expectations,
 
estimates, schedules and costs; expectations relating
 
to licences and leases;
oil, gas, alternative fuel and energy prices, volatility, supply and demand; plans
 
and expectations regarding processes related
 
to human rights
laws, corporate structure and organizational policies;
 
technological innovation, implementation, position
 
and expectations; expectations
regarding role and composition of the board and
 
our remuneration policies; our goal of
 
safe and efficient operations; effectiveness of our
internal policies and plans; our ability to manage
 
our risk exposure, our liquidity levels and
 
management of liquidity reserves; estimated or
future liabilities, obligations or expenses; expected
 
impact of currency and interest rate fluctuations
 
and LIBOR discontinuation; projected
outcome, impact or timing of HSE regulations; HSE
 
goals and objectives of management for
 
future operations; our ambitions and plans
regarding biodiversity (including our aim to develop
 
a net-positive impact approach for projects)
 
and value creation for society; expectations
related to regulatory trends; impact of PSA effects; projected
 
impact or timing of administrative or governmental
 
rules, standards, decisions,
standards or laws (including taxation laws); projected
 
impact of legal claims against us; plans
 
for capital distribution, share buy-backs and
amounts and timing of dividends are forward-looking
 
statements.
You should not place undue reliance on these forward-looking statements. Our actual results
 
could differ materially from those anticipated in
the forward-looking statements for many reasons, including
 
the risks described in the risk factors incorporated
 
in Item 3.D of this 2022 Form
20-
F.
 
These forward-looking statements reflect current views about
 
future events, are based on management’s current expectations
 
and
assumptions and are, by their nature, subject to
 
significant risks and uncertainties because they relate
 
to events and depend on circumstances
that will occur in the future. There are a number
 
of factors that could cause actual results and
 
developments to differ materially from those
expressed or implied by these forward-looking statements,
 
including levels of industry product supply, demand and pricing, in particular in
 
light
of significant oil price volatility and the uncertainty
 
caused by the European security situation, including
 
Russia’s invasion of Ukraine;
unfavorable macroeconomic conditions and inflationary
 
pressures; exchange rate and interest rate
 
fluctuations; levels and calculations of
reserves and material differences from reserves estimates;
 
regulatory stability and access to resources, including
 
attractive low carbon
opportunities; the effects of climate change and changes
 
in stakeholder sentiment and regulatory requirements
 
regarding climate change;
changes in market demand and supply for renewables;
 
inability to meet strategic objectives; the development
 
and use of new technology;
social and/or political instability, including as a result of Russia’s invasion of Ukraine;
 
failure to manage digital and cyber threats; operational
problems; unsuccessful drilling; availability of adequate
 
infrastructure; the actions of field partners
 
and other third-parties; reputational damage;
the actions of competitors; the actions of the Norwegian
 
state as majority shareholder and exercise of ownership
 
by the Norwegian state;
changes or uncertainty in or non-compliance with
 
laws and governmental regulations; adverse changes
 
in tax regimes; the political and
economic policies of Norway and other oil-producing
 
countries; regulations on hydraulic fracturing and
 
low-carbon value chains; liquidity,
interest rate, equity and credit risks; risks relating
 
to trading and commercial supply activities;
 
an inability to attract and retain personnel;
ineffectiveness of crisis management systems; inadequate insurance
 
coverage; health, safety and environmental risks; physical
 
security risks;
failure to meet our ethical and social standards;
 
non-compliance with international trade sanctions;
 
and other factors discussed elsewhere in
this 2022 Form 20-F.
 
The achievement of Equinor’s climate ambitions
 
depends, in part, on broader societal shifts in
 
consumer demands and technological
advancements, each of which are beyond Equinor’s
 
control. Should society’s demands and technological innovation
 
not shift in parallel with
Equinor’s pursuit of its energy transition plan,
 
Equinor’s ability to meet its climate ambitions
 
will be impaired. The calculation of Equinor’s
 
net
carbon intensity presented in this report includes an
 
estimate of emissions from the use of sold products
 
(GHG protocol category 11) as a
means to more accurately evaluate the emission lifecycle
 
of what we produce to respond to the energy
 
transition and potential business
opportunities arising from shifting consumer demands.
 
Including these emissions in the calculations should
 
in no way be construed as an
acceptance by Equinor of responsibility for the
 
emissions caused by such use.
The reference to any scenario in this report, including
 
any potential net-zero scenarios, does not imply
 
Equinor views any particular scenario
as likely to occur. Third-party scenarios discussed in this report reflect
 
the modeling assumptions and outputs of their respective
 
authors, not
Equinor, and their use by Equinor is not an endorsement by Equinor
 
of their underlying assumptions, likelihood or probability. Investment
decisions are made on the basis of Equinor’s
 
separate planning process. Any use of the modeling
 
of a third-party organization within this
report does not constitute or imply an endorsement
 
by Equinor of any or all of the positions or
 
activities of such organization.
Although we believe that the expectations reflected
 
in the forward-looking statements are reasonable,
 
we cannot assure you that our future
results, level of activity, performance or achievements will meet these expectations.
 
Moreover, neither we nor any other person assumes
responsibility for the accuracy and completeness of
 
the forward-looking statements. Unless we are required
 
by law to update these
statements, we will not necessarily update any of
 
these statements after the date of this 2022
 
Form 20-F, either to make them conform to
actual results or changes in our expectations.
Part I
ITEM 1. IDENTITY OF DIRECTORS, SENIOR MANAGEMENT AND ADVISERS
A.
 
Directors and Senior Management
Not applicable.
B.
 
Advisers
Not applicable.
C.
 
Auditors
Not applicable.
ITEM 2. OFFER STATISTICS
 
AND EXPECTED TIMETABLE
A.
 
Offer statistics
Not applicable.
B.
 
Method and Expected Timetable
Not applicable.
ITEM 3. KEY INFORMATION
A.
 
[Reserved]
B.
 
Capitalization and Indebtedness
Not applicable.
C.
 
Reason for the Offer and Use of Proceeds
Not applicable.
D.
 
Risk Factors
The information set forth under the heading “
Risk Factors
” in section 5.2 of chapter 5 on pages 277 – 282 of the 2022 Annual
Report is incorporated herein by reference.
ITEM 4. INFORMATION ON THE COMPANY
A.
 
History and Development of the Company
Equinor ASA was incorporated on 18 September 1972, is a public limited liability company
 
organised under the laws of Norway
and is subject to the provisions of the Norwegian Public Limited Liability Companies Act. Equinor’s
 
head office is located at Forusbeen
50, 4035 Stavanger, Norway. The telephone number of its principal place of business is +47-5199-00 00.
The information set forth under the following headings of the 2022 Annual Report is incorporated
 
herein by reference:
●
 
Equinor in 2022 on page 11;
●
 
Equinor’s Energy transition plan on pages 12 – 15;
●
 
Our history in Section 1.2 of Chapter 1 on pages 18 – 19;
●
 
Investments in Section 2.2.2 of Chapter 2 on pages 87 – 88;
●
 
Key events in Section 3.1.1 of Chapter 3 on pages 116 – 117;
●
 
Projects under development, Decommissioning on the NCS and Climate measures in Section 3.1.1
 
of Chapter 3
on pages 122 – 124;
●
 
Key events in Section 3.1.2 of Chapter 3 on pages 125 – 126;
●
 
Fields under development internationally in Section 3.1.2 of Chapter 3 on page 130;
●
 
Key events in Section 3.1.3 of Chapter 3 on page 132;
●
 
Fields under development in the US in Section 3.1.3 of Chapter 3 on page 135;
●
 
Overview in Section 3.2 of Chapter 3 on pages 136 – 138;
●
 
Key events in Section 3.3 of Chapter 3 on pages 142 – 143; and
●
 
Key projects in Section 3.3 of Chapter 3 on page 146.
The information set forth in the third and fourth paragraphs of the section entitled “
Introduction
” of this 2022 Form 20-F is also
incorporated herein by reference. See also notes 5 Segments and 6 Acquisitions and
 
disposals to the Consolidated financial
statements.
B.
 
Business Overview
The information set forth under the following headings of the 2022 Annual Report is incorporated
 
herein by reference:
●
 
Key figures 2022 on pages 4 – 6;
●
 
Key figures – segment performance on page 6;
●
 
This is Equinor in Section 1.1 of Chapter 1 on page 17;
●
 
Our Business in Section 1.3 of Chapter 1 on pages 20 – 22;
●
 
Equinor’s market perspective in Section 1.4 of Chapter 1 on pages 23 – 24;
●
 
Equinor’s Strategy in Section 1.5 of Chapter 1 on pages 25 – 29;
●
 
Sustainability at Equinor in Section 1.7 of Chapter 1 on page 32;
●
 
Performance 2022 on pages 45 – 46 of Chapter 2;
●
 
Safe and secure operations in Section 2.1.1 of Chapter 2 on pages 49 – 54;
●
 
Management approach in Section 2.1.2 of Chapter 2 on pages 55 – 56;
●
 
Performance evaluation in Section 2.1.2 of Chapter 2 on pages 58 – 59;
●
 
Management approach in Section 2.1.3 of Chapter 2 on pages 60 – 61;
●
 
Performance evaluation in Section 2.1.3 of Chapter 2 on page 63;
●
 
Management approach in Section 2.1.4 of Chapter 2 on pages 64 – 65;
●
 
Performance evaluation in Section 2.1.4 of Chapter 2 on pages 68 – 69;
●
 
Management approach in Section 2.2.3 of Chapter 2 on page 91;
●
 
Procurement and ripple effects in Section 2.2.3 of Chapter 2 on page 92;
●
 
Performance evaluation in Section 2.2.3 of Chapter 2 on page 93;
●
 
Management approach in Section 2.2.4 of Chapter 2 on pages 94 – 95;
●
 
Performance evaluation in Section 2.2.4 of Chapter 2 on page 97;
●
 
Exploration & Production Norway in Section 3.1.1 of Chapter 3 on pages 116
 
– 124;
●
 
Exploration & Production International in Section 3.1.2 of Chapter 3 on pages 125 – 131;
●
 
Exploration & Production USA in Section 3.1.3 of Chapter 3 on pages 132 – 135;
●
 
High-value growth in renewables in Section 3.2 of Chapter 3 on pages 136 – 139;
●
 
Marketing, midstream and processing (MMP), including new market opportunities in low carbon
 
solutions in
Section 3.3 of Chapter 3 on pages 140 – 148; and
●
 
Other group in Section 3.4 of Chapter 3 on page 149.
See also notes 5 Segments and 7 Total revenues and other income to the Consolidated financial statements.
The information about Equinor’s competitive position in the sections of the 2022 Annual
 
Report that are incorporated by
reference herein is based on several sources such as investment analyst reports, independent
 
market studies, and internal
assessments of market share based on publicly available information about the financial results
 
and performance of market players.
Applicable laws and regulations
Equinor operates in around 30 countries and is exposed and committed to compliance with numerous laws
 
and regulations
globally. The graphic entitled ‘Where we are’ in Section 1.3 of Chapter 1 and the risks set forth under the heading ‘Policies and
legislation’ in Section 5.2 of Chapter 5 of the 2022 Annual Report are also incorporated
 
herein by reference.
This section gives a general description on the legal and regulatory framework in the various jurisdictions
 
where Equinor operates and
in particular in the countries of Equinor’s core activities.
Regulatory framework for upstream oil and gas operations
Currently, Equinor is subject to two main regimes applicable to petroleum activities worldwide:
●
 
Corporate income tax regimes; and
●
 
Production sharing agreements (PSAs)
Equinor is also subject to a wide variety of health, safety and environmental (HSE) laws and
 
regulations concerning its products,
operations and activities. Relevant laws and regulations include jurisdiction specific laws
 
and regulations, international regulations,
conventions or treaties, as well as EU directives and regulations.
Concession regimes
Under a concession regime, companies are granted licences by the government to extract petroleum.
 
This is similar to the
Norwegian system described below. Typically,
 
the licences are offered to pre-qualified companies following bidding rounds. The
criteria for the evaluation of bidding offers under these regimes can be the level of offered signature bonus (bid
 
amount), minimum
exploration programme, and local content. In exchange for those commitments, the successful
 
bidder(s) receive a right to explore,
develop and produce petroleum within a specified geographical area for a limited period of time.
 
The terms of the licences are usually
not negotiable. The fiscal regime may entitle the relevant jurisdiction to royalties,
 
profit tax or special petroleum tax.
PSA regimes
PSAs are normally awarded to the contractor parties after bidding rounds announced by the
 
government. Main bid parameters
are a minimum exploration programme and signature bonuses, allocation of profit oil and, in some
 
cases, tax.
Under a PSA, the host government typically retains the right to the hydrocarbons in place. The
 
contractor receives a share of the
production for services performed. Normally, the contractor carries the exploration and development costs and risk prior to a
commercial discovery and is then entitled to recover those costs during the production phase. The remaining
 
share of the production -
the profit share, is split between the government and the contractor according to a mechanism set
 
out in the PSA. The contractor is
usually subject to income tax on its own share of the profit oil. Fiscal provisions in
 
a PSA are to a large extent negotiable and are
unique to each PSA.
Norway
Norway is not a member of the European Union (EU) but is a member of the European
 
Free Trade Association (EFTA). The EU
and the EFTA Member States have entered into the Agreement on the European Economic Area, referred to as the EEA Agreement,
which provides for the inclusion of EU legislation in the national law of the EFTA Member States (except Switzerland). Equinor’s
business activities are subject to both the EFTA Convention and EU laws and regulations adopted pursuant to the EEA Agreement.
The principal laws governing Equinor’s petroleum activities in Norway and on the NCS
 
are the Norwegian Petroleum Act of 29
November 1996 (the Petroleum Act) and the regulations issued thereunder, and the Norwegian Petroleum Taxation Act of 13 June
1975 (the Petroleum Taxation Act).
Under the Petroleum Act, the Norwegian Ministry of Petroleum and Energy (“MPE”) is responsible
 
for resource management and
for administering petroleum activities on the NCS. The main task of the MPE is to
 
ensure that petroleum activities are conducted in
accordance with the applicable legislation, the policies adopted by the Norwegian Parliament (the
 
Storting) and relevant decisions of
the Norwegian State.
The Storting’s role in relation to major policy issues in the petroleum sector can affect Equinor in two ways: first, when the
Norwegian State acts in its capacity as majority owner of Equinor shares and, second, when the
 
Norwegian State acts in its capacity
as regulator:
●
 
The Norwegian State’s shareholding in Equinor is managed by the Ministry of Trade, Industry and Fisheries. The Ministry will
normally decide how the Norwegian State will vote on proposals submitted to general meetings
 
of the shareholders. However, in
certain exceptional cases, it may be necessary for the Norwegian State to seek approval
 
from the Storting before voting on a
certain proposal. This will normally be the case if Equinor issues additional shares and such issuance
 
would significantly dilute
the Norwegian State’s holding, or if such issuance would require a capital contribution from the Norwegian State
 
in excess of
government mandates. A vote by the Norwegian State against an Equinor proposal to issue
 
additional shares would prevent
Equinor from raising additional capital in this manner and could adversely affect Equinor’s ability
 
to pursue business
opportunities. The information regarding the Norwegian State’s ownership in the information set forth under the heading
 
“Major
Shareholders” in Section 5.3 of Chapter 5 and the risks set forth in “Ownership and action
 
by the Norwegian State” in Section 5.2
of Chapter 5 of the 2022 Annual Report are also incorporated herein by reference.
 
●
 
The Norwegian State exercises important regulatory powers over Equinor, as well as over other companies and corporations on
the NCS. As part of its business, Equinor or the partnerships to which Equinor is a party, frequently need to apply for licences
and other approvals from the Norwegian State. Although Equinor is majority-owned by the
 
Norwegian State, it does not receive
preferential treatment with respect to licences granted by or under any other regulatory rules enforced
 
by the Norwegian State.
The Petroleum Act sets out the principle that the Norwegian State is the owner of all subsea
 
petroleum on the NCS, that the
exclusive right to resource management is vested in the Norwegian State and that the Norwegian
 
State alone is authorised to award
licences for petroleum activities as well as determine their terms. Licensees are required to submit
 
a plan for development and
operation (PDO) to the MPE for approval. For fields of a certain size, the Storting has to
 
accept the PDO before it is formally approved
by the MPE. Equinor is dependent on the Norwegian State for approval of its NCS exploration
 
and development projects and its
applications for production rates for individual fields.
Production licences are the most important type of licence awarded under the Petroleum Act. A
 
production licence grants the
holder an exclusive right to explore for and produce petroleum within a specified geographical
 
area. The licensees become the
owners of the petroleum produced from the field covered by the licence. Production licences
 
are normally awarded for an initial
exploration period, which is typically six years, but which can be shorter. The maximum period is ten years. During this exploration
period, the licensees must meet a specified work obligation set out in the licence. If the licensees
 
fulfil the obligations set out in the
initial licence period, they are entitled to require that the licence be extended for
 
a period specified at the time when the licence is
awarded, typically 30 years.
The terms of the production licences are decided by the MPE. Production licences are
 
awarded to groups
 
of companies forming a
joint venture at the MPE’s discretion. The members of the joint venture are jointly and severally liable to
 
the Norwegian State for
obligations arising from petroleum operations carried out under the licence. The MPE decides
 
the form of the joint operating
agreements and accounting agreements. The MPE uses the same standard form of joint operating
 
agreement and accounting
agreement for all licenses.
The governing body of the joint venture is the management committee. In licences awarded
 
since 1996 where the State’s direct
financial interest (SDFI) holds an interest, the Norwegian State, acting through Petoro AS, may veto
 
decisions made by the joint
venture management committee, which, in the opinion of the Norwegian State, would not be in compliance
 
with the obligations set
forth in the licence with respect to the Norwegian State’s exploitation policies or financial interests. This
 
power of veto has never been
used.
Interests in production licences may be transferred directly or indirectly subject to the consent
 
of the MPE and the approval of the
tax treatment by the Ministry of Finance. In most licences, there are no pre-emption rights in favour
 
of the other licensees. However,
the SDFI, or the Norwegian State, as appropriate, still hold pre-emption rights in all licences.
The day-to-day management of a field is the responsibility of an operator appointed by the MPE.
 
The operator is in practice
always a member of the joint venture holding the production licence, although this is not legally
 
required. The terms of engagement of
the operator are set out in the joint operating agreement.
If important public interests are at stake, the Norwegian State may instruct the operators on the
 
NCS to reduce the production of
petroleum. An example of this occurred in May 2020, when the Norwegian State imposed
 
a reduction in oil production for the rest of
the year, due to the Covid-19 pandemic that led to a lower demand for oil and gas. The reduction in production was
 
distributed
between all fields on a pro rata basis.
A licence from the MPE is also required in order to establish facilities for the transportation
 
and utilisation of petroleum.
Ownership of most facilities for the transportation and utilisation of petroleum in Norway
 
and on the NCS is organised in the form of
joint ventures. The participants’ agreements are similar to joint operating agreements for production.
Licensees are required to prepare a decommissioning plan before a production licence or a licence to establish
 
and use facilities
for the transportation and utilisation of petroleum expires or is relinquished, or the use of a
 
facility ceases. On the basis of the
decommissioning plan, the MPE makes a decision as to the disposal of the facilities.
The information regarding Equinor’s activities and shares in Equinor’s production
 
licences on the NCS, set forth under the
heading ‘Exploration & Production Norway’ in Section 3.1.1 of Chapter 3 of the 2022 Annual Report
 
is incorporated herein by
reference.
On 1 July 2022, the MPE decided that parts of the Norwegian Security Act would apply
 
to Equinor. This enables Equinor to
receive and handle classified information from the authorities. In 2023, the MTIF and the MPE notified that
 
the Security Act will apply
in its entirety to Equinor as an undertaking controlling infrastructure and engaging in
 
activities which are of vital importance to
fundamental national functions. The Security Act entered into force 1 January 2019 and is
 
designed to protect national security
interests. The National Security Authority supervises undertakings which are covered
 
by the act.
Gas sales and transportation from the NCS
Equinor markets gas from the NCS on its own behalf and on the Norwegian State’s behalf. Dry
 
gas is mainly transported through
the Norwegian gas transport system (Gassled) to customers in the UK and mainland Europe,
 
while liquified natural gas is transported
by vessels to worldwide destinations.
The Norwegian gas transport system, consisting of the pipelines and terminals through which
 
licensees on the NCS transport
their gas, is owned by a joint venture called Gassled. The Norwegian Petroleum Act
 
of 29 November 1996 and the pertaining
Petroleum Regulation establish the basis for non- discriminatory third-party access to the Gassled transport
 
system.
The tariffs for the use of capacity in the transport system are determined by applying a formula set out in
 
separate tariff
regulations stipulated by the MPE. The tariffs are paid for booked capacity rather than the volumes
 
actually transported.
The information set forth under the heading ‘
Marketing, midstream and processing (MMP), including new market opportunities in
low carbon solutions
’ in Section 3.3 of Chapter 3 of the 2022 Annual Report is also incorporated
 
herein by reference.
The Norwegian State's participation
In 1985, the Norwegian State established the State’s direct financial interest (SDFI) through which the Norwegian
 
State has direct
participating interests in licences and petroleum facilities on the NCS. As a result, the Norwegian
 
State holds interests in a number of
licences and petroleum facilities in which Equinor also holds interests. Petoro AS, a company wholly
 
owned by the Norwegian State,
was formed in 2001 to manage the SDFI assets.
The Norwegian State has a coordinated ownership strategy aimed at maximising the aggregate value
 
of its ownership interests in
Equinor and the Norwegian State’s oil and gas. This is reflected in the Owner’s Instruction
 
described below, which contains a general
requirement that, Equinor, in its activities on the NCS, take account of these ownership interests in decisions that may affect the
execution of this marketing arrangement.
SDFI oil and gas marketing and sale
Equinor markets and sells the Norwegian State’s oil and gas together with Equinor’s
 
own production. The arrangement has been
implemented by the Norwegian State through a separate instruction (the Owner’s
 
Instruction) adopted by an extraordinary
shareholder meeting in 2001, with the Norwegian State as sole shareholder at the time.
 
The Owner’s Instruction sets out the specific
terms for the marketing and sale of the Norwegian State’s oil and gas.
Equinor is obliged under the Owner’s Instruction to jointly market and sell the Norwegian State’s
 
oil and gas as well as Equinor’s
own oil and gas. The overall objective of the marketing arrangement is to obtain the highest
 
possible total value for Equinor’s oil and
gas and the Norwegian State’s oil and gas, and to ensure an equitable distribution of the total value creation
 
between the Norwegian
State and Equinor.
The Norwegian State may at any time utilise its position as majority shareholder of Equinor
 
to withdraw or amend the Owner’s
Instruction.
US
Petroleum activities in the US are extensively regulated by multiple agencies in the US
 
federal government, and by tribal, state
and local regulation. The US government directly regulates development of hydrocarbons
 
on federal lands, in the US Gulf of Mexico,
and in other offshore areas. Different federal agencies directly regulate portions of the industry, and other general regulations related
to environmental, safety, and physical controls apply to all aspects of the industry. In addition to regulation by the US federal
government, any activities on US tribal lands (indigenous persons’ semi-sovereign territory)
 
are regulated by governments and
agencies in those areas. Significantly for Equinor’s US onshore interests, each
 
individual state has its own regulations of all aspects of
hydrocarbon development within its borders. A recent trend also includes local municipalities
 
adopting their own hydrocarbon
regulations.
In the US, hydrocarbon interests are considered a private property right. In areas owned by the US
 
government, that means that
the government owns the minerals in its capacity as landowner. The federal government, and each tribal and state government,
establishes the terms of its own leases, including the length of time of the lease,
 
the royalty rate, and other terms.
The vast majority of onshore minerals, including hydrocarbons, in every US state in which Equinor has onshore
 
interests, belong
to private individuals.
In order to explore for or develop hydrocarbons, a company must enter into a lease agreement with the applicable governmental
agency for federal, state or tribal land, and for private lands, with each owner of the minerals the
 
company wishes to develop. In each
lease, the lessor retains a royalty interest in the production (if any) from the leased area. The
 
lessee owns a working interest and has
the right to explore and produce oil and gas. The lessee incurs all the costs and liabilities
 
but will share only the portion of the revenue
that is net of costs and expenses and not reserved to the lessor through its royalty interest.
Leases typically have a primary term for a specified number of years (from one to ten years)
 
and a conditional secondary term
that is tied to the production life of the properties. If oil and gas is being produced in
 
paying quantities at the end of the primary term,
or the operator satisfies other obligations specified in the agreement, the lease typically continues beyond
 
the primary term (Held by
Production). Leases typically involve paying the lessor both a signing bonus based on the number of
 
leased acres and a royalty
payment based on the production.
Each US state has its own agencies that regulate the development, exploration, and production
 
of oil and gas activities. These
state agencies issue drilling permits and control pipeline transportation within state boundaries. The state agencies particularly
relevant to Equinor’s US onshore activities include: (a) Pennsylvania Department
 
of Environmental Protection’s Office of Oil and Gas
Management, (b) Ohio Department of Natural Resources, Division of Oil and Gas, and (c) West Virginia Department of
 
Environmental
Protection. In addition, some state utility departments handle pipeline transportation within state
 
boundaries, and each state also has
its own department regulating environmental, health, and safety issues arising from oil and
 
gas operations.
Brazil
In Brazil, licences are mainly awarded according to a concession regime or a production sharing
 
regime (the latter specifically for
areas within the pre-salt polygon area or strategic areas) by the Federal Government. All state-owned
 
and private oil companies may
participate in the bidding rounds provided they follow the bidding rules and meet the qualification
 
criteria. The tender protocol issued
for each bidding round contains the draft of the concession agreement or the production sharing
 
agreement that the winners must
adhere to without the possibility of negotiating its terms, i.e., all the agreements signed under a
 
certain bidding round contain the
same general provisions and only differ in the particular items presented in the offers. There is no restriction
 
on foreign participation,
provided that the foreign investor incorporates a company under the Brazilian law for signing the
 
agreement and complies with the
requirements established by the Brazilian National Agency of Petroleum, Natural Gas and Biofuels
 
(ANP).
The current criteria for the evaluation of bidding offers under the concession regime are: (a) signature bonus;
 
and (b) minimum
exploration program. However, in past bidding rounds the participants also had to offer a local content percentage as a firm
commitment. Companies can bid individually or in consortium always observing the qualification
 
criteria for operator and non-
operators.
The concession agreements are signed by ANP on behalf of the Federal Government. Generally, concessions are granted for a
total period of 35 years and typically the exploration phase lasts from two to eight
 
years, while the production phase may last 27 years
from the declaration of commerciality. Concessionaires are entitled to request the extension of each of these phases, subject to ANP
approval.
In bidding rounds involving the production sharing regime, the law grants to the Brazilian government-controlled
 
company
Petroleo Brasileiro S.A. – Petrobras, a right of preference to be the sole operator in the pre-salt
 
fields, with a minimum 30% of
participating interest. If this right is exercised, Petrobras may still participate in the bidding round
 
and present offers for the remaining
70% under the same conditions applicable to other participants. Likewise, in the concession
 
bidding rounds, companies may bid
individually or together with other companies. The winners are required to form a consortium with
 
Pre-Sal Petroleo S.A. (PPSA), a
Brazilian state-owned company, which is responsible for managing the production sharing agreement and selling the production
allocated to the Government under the profit oil. PPSA appoints 50% of the members
 
of the operating committee, including the
chairperson, in addition to certain veto rights and casting vote.
The current criteria for the evaluation of bidding offers under the production sharing regime is the offered percentage of profit oil.
The winner will be the company which offers the highest percentage to the government in accordance with the technical
 
and
economic parameters established for each block in the tender documents under a certain bidding
 
round.
Production sharing contracts are signed by the Ministry of Mines and Energy on behalf of the
 
Federal Government. Generally, the
contracts are valid for a period of 35 years which, by law, cannot be extended. Of the two phases of the contract – exploration and
production – the exploration phase may be extended provided that the total period of the contract
 
remains as 35 years.
In order to perform the exploration and exploitation of oil and gas reserves, companies must
 
obtain an environmental license
granted by the Brazilian Institute of Environment and Renewable Natural Resources (IBAMA), which,
 
together with ANP, is
responsible for the safety and environmental regulations regarding upstream activities.
HSE regulation relevant for the Norwegian upstream oil and gas activities in Norway
Equinor’s oil and gas operations in Norway must be conducted in compliance with
 
a reasonable standard of care, taking into
consideration the safety of workers, the environment and the economic values of installations
 
and vessels. The Petroleum Act
specifically requires that petroleum operations are carried out in such a manner that a high level of safety
 
is maintained and
developed in step with technological developments. Equinor is also required at all times to
 
have a plan to deal with emergency
situations in Equinor’s petroleum operations. During an emergency, the Norwegian Ministry of Labour and Social Inclusion/Norwegian
Ministry of Transport/Norwegian Coastal Administration may decide that other parties should provide the necessary resources, or
otherwise adopt measures to obtain the necessary resources, to deal with the emergency for
 
the licensees’ account.
Liability for pollution damage
The Norwegian Petroleum Act imposes strict liability for pollution damage regardless of fault. Accordingly, as a holder of licences
on the NCS, Equinor is subject to statutory strict liability under the Petroleum Act as a result
 
of pollution caused by spills or discharges
of petroleum from petroleum facilities in any of Equinor’s licences.
A claim against the license holders for compensation relating to pollution damage shall initially
 
be directed to the operator, which
in accordance with the terms of the joint operating agreement, will distribute the claim
 
to the other licensees in accordance with their
participating interest in the licences.
Discharge permits
Emissions and discharges from Norwegian petroleum activities are regulated through several acts,
 
including the Petroleum Act,
the CO
2
 
Tax Act, the Sales Tax
 
Act, the Greenhouse Gas Emission Trading Act and the Pollution Control Act. Discharge of oil and
chemicals in relation to exploration, development and production of oil and natural gas
 
are regulated under the Pollution Control Act.
In accordance with the provisions of this Act, an operator must apply for a discharge permit from
 
relevant authorities on behalf of the
licence group in order to discharge any pollutants into water. Further, the Petroleum Act states that burning of gas in flares beyond
what is necessary for safety reasons to ensure normal operations is not permitted without approval
 
from the MPE. All operators on the
NCS have an obligation to, and are responsible, for establishing sufficient procedures for the monitoring and
 
reporting of any
discharge into the sea. The Norwegian
 
Environment Agency, the Norwegian Petroleum Directorate and the Norwegian Oil Industry
Association have established a joint database for reporting emissions to air and discharges
 
to sea from the petroleum activities, the
Environmental Web (EW). All operators on the NCS report emission and discharge data directly into the database.
Regulations on reduction of carbon emissions and CO
2
 
storage
Equinor’s operations in Norway are subject to emissions taxes as well as emissions
 
allowances granted for Equinor’s larger
European operations under the emissions trading scheme. The agreed strengthening of the EU’s
 
emission trading scheme is
expected to affect energy and industry installations, which include Equinor’s installations at the NCS.
 
The price of emissions
allowances has increased significantly since the reforms to the EU Emission Trading Scheme in 2018, and is expected to increase
further towards 2030.
The Norwegian Climate Act promotes the implementation of Norway's climate targets as
 
part of the transition to a low-emission
society in Norway in 2050. This act may influence our activities through plans and actions
 
implemented by the state to achieve these
targets and reference is made to the Climate Plan 2021- 2030 launched 8 January 2021 by
 
the Norwegian Government for
achievement of at least 50% and towards 55% reduction in GHG emissions in
 
2030 compared to 1990 levels. The Climate Plan states
that the carbon cost for offshore oil & gas production in Norway will increase to 2000 NOK/t
 
CO2 towards 2030. The Norwegian
Government has recently presented an update of the plan, which sets out how to achieve
 
its transition target of reducing Norway's
own emissions by 55%.
EU directive 2009/31/EU on storage of CO
2
 
is implemented in the Pollution Control Act and the Petroleum Act and in regulations
adopted under the Petroleum Act. The CO
2
 
capture and storage at Equinor’s Sleipner and Snøhvit fields as well
 
as the Northern
Lights and Smeaheia projects are governed by these regulations.
HSE regulation of upstream oil and gas activities in the US
Equinor’s upstream activities in the US are heavily regulated at multiple levels, including
 
federal, state, and local municipal
regulation. Equinor is subject to those regulations as a part of its activities in the US
 
onshore (including Equinor’s assets in Ohio,
Pennsylvania and West Virginia), and in the US Gulf of Mexico.
The National Environmental Policy Act of 1969 is an umbrella procedural statute that requires
 
federal agencies to consider the
environmental impacts of their actions. Several substantive US federal statutes specifically cover
 
certain potential environmental
effects of hydrocarbon extraction activities. Those include: the Clean Air Act, which regulates air quality
 
and emissions; the Federal
Water Pollution Control Act (commonly known as the Clean Water Act), which regulates water quality and discharges; the Safe
Drinking Water Act, which establishes drinking water standards for tap water and underground injection rules; the Resource
Conservation and Recovery Act of 1976, which regulates hazardous and solid waste management;
 
the Comprehensive Environmental
Response, Compensation and Liability Act of 1980, which addresses remediation of legacy
 
disposal sites and release reporting; and
the Oil Pollution Act, which provides for oil spill prevention and response.
Other US federal statutes are resource-specific. The Endangered Species Act of 1973 protects listed
 
endangered and threatened
species and critical habitat. Other statutes protect certain species, including the Migratory Bird
 
Treaty Act, the Bald and Golden Eagle
Protection Act and the Marine Mammal Protection Act of 1972. Other statutes govern natural resource
 
planning and development on
federal lands onshore and on the Outer Continental Shelf (OCS), including: the Mineral
 
Leasing Act; the Outer Continental Shelf
Lands Act; the Federal Land Policy and Management Act of 1976; the Mining Law
 
of 1872; the National Forest Management Act of
1976; the National Park Service Organic Act; the Wild and Scenic Rivers Act; the National
 
Wildlife Refuge System Administration Act
of 1966; the Rivers and Harbors Appropriation Act; and the Coastal Zone Management
 
Act of 1972.
The federal government regulates offshore exploration and production for the OCS, which extends from the
 
edge of state waters
(either 3 or 9 nautical miles from the coast, depending on the state) out to the edge of national
 
jurisdiction, 200 nautical miles from
shore. The Bureau of Ocean Energy Management (BOEM) manages federal OCS leasing
 
programs, conducts resource assessments,
and licences seismic surveys. The Bureau of Safety and Environmental Enforcement (BSEE) regulates
 
all OCS oil and gas drilling
and production. The Office of Natural Resources Revenue (ONRR) collects and disburses rents
 
and royalties from offshore and
onshore federal and Native American lands.
Additional federal statutes cover certain products or wastes, and focus on human health and
 
safety: the Toxic Substances
Control Act regulates new and existing chemicals and products that contain these chemicals; the
 
Hazardous Materials Transportation
Act regulates transportation of hazardous materials; the Occupational Safety and Health Act of
 
1970 regulates hazards in the
workplace; the Emergency Planning and Community Right-to-Know Act of 1986 provides emergency
 
planning and notification for
hazardous and toxic chemicals.
The federal and state governments share authority to administer some federal environmental programs (e.g.,
 
the Clean Air Act
and Clean Water Act). States also have their own, sometimes more stringent, environmental laws. Counties, cities and other local
government entities may have their own requirements as well.
Equinor continually monitors regulatory and legislative changes at all levels and engages in the
 
stakeholder process through
trade associations and direct comments to suggested regulatory and legislative regimes, to ensure
 
that its operations remain in
compliance with all applicable laws and regulations. In particular, BSEE drilling and production regulations were extensively revised in
response to the 2010 Deepwater Horizon blowout and oil spill. The revised regulatory regime
 
includes requirements for enhanced well
design, improved blowout preventer design, testing and maintenance, and an increased number
 
of trained inspectors. The Biden
Administration continues to review and revise these regulations, and Equinor is engaged with
 
relevant governmental and industry
stakeholders to ensure that Equinor’s operations remain in compliance.
HSE regulation of upstream oil and gas activities in Brazil
Equinor’s oil and gas operations in Brazil must be conducted in compliance with
 
a reasonable standard of care, taking into
consideration the safety and health of workers and the environment. The Brazilian Petroleum Law (Law
 
No. 9,478/97) describes the
government’s policy objectives for the rational use of the country’s energy resources, including the protection of the environment. In
addition to the Petroleum Law, Equinor is also subject to many other laws and regulations issued by different authorities, including
ANP,
 
IBAMA, Federal Environmental Council (CONAMA) and Brazilian Navy. All those authorities have the power to impose fines in
case of non-compliance with the respective rules. The concession and production sharing contracts
 
also impose obligations on
operators and consortium members, who are jointly and severally liable. They must,
 
at their own account and risk, assume and fully
respond to all losses and damages caused directly or indirectly by the applicable consortium’s operations and their
 
performance
irrespective of fault, to the ANP, the Federal Government and third parties.
The exploration, drilling and production of oil and gas depend on environmental licences which
 
define the conditions for the
implementation of the project and compliance measures to mitigate and control environment impact. Equinor
 
is subject to fines and
even licence suspension and/or cancellation in case of non-compliance with such conditions.
In Brazil, Equinor is also required to have an emergency response system as per ANP Ordinance
 
44/2009 to deal with
emergency situations in its petroleum operations, as well as an oil spill response plan for each asset
 
to minimise the environmental
impact of any environmental unexpected situation that may generate spill of oil or chemical to
 
sea.
Discharge permits
Discharges from Brazilian petroleum activities are regulated through several acts, including the CONAMA
 
Resolution 393/2007
for produced water, CONAMA Resolution No. 357/2005 and CONAMA Resolution No. 430/2011 for effluents (sewage, etc) and
IBAMA technical instructions for drilling waste. According to Environmental Ministry Ordinance No.
 
422/2011, the discharge of
chemicals in connection with exploration, development and production of oil and natural gas is
 
assessed as part of the permitting
process and the operator must apply for any discharge permit from relevant authorities on behalf
 
of the licence group in order to
discharge any pollutants into the water.
Regulations on reduction of carbon emissions
Although Equinor’s operations in Brazil are not subject to emissions taxes (CO
2
 
limit) yet, there are initiatives within the Brazilian
congress for the establishment of a carbon market. At this point it is unclear if and when these initiatives
 
will be turned into law.
The CONAMA Regulation No. 382/06 regulates air emissions limits for pollutant gases (e.g. NOx) from
 
all fixed sources that have
total power consumption higher than 100MW.
Gas flares must be authorised by the ANP under ANP Resolution No. 806/2020, which also
 
sets out cases in which ANP
authorisation is not necessary.
The Brazilian government signed the Paris Agreement in 2015. During COP26, Brazil updated its
 
ambition to reduce its
greenhouse gas emissions by 37% until 2025 and 50% until 2030, compared to 2005 levels. Because
 
of the desire to boost the
economy and an expected growing energy demand, the focus on emissions reduction is
 
on improved control of Forests and Land Use
and for that Brazil continue to adhere to the Forest for Deal agreement, committing
 
to take actions to reduce illegal deforestation until
2030. The country also adheres to the Global Methane Pledge.
To meet the growing energy demand challenge, the Brazilian government has indicated acceptance for an increase in total
emissions in the short term from the industrial and power generation sectors, although the efficiency in power
 
generation and usage
will certainly be an important part of the Brazilian government’s future approach to the issue.
Regulatory framework for renewable energy operations
Equinor’s renewables positions currently mainly consist of offshore wind farms in operation and
 
development in the UK, the state
of New York and Poland. In these jurisdictions the legislation is structured around a lease where permission to develop is granted
following a series of approvals relating largely to environmental and social impact assessments. The government
 
separately auctions
a subsidized power purchase price either through renewable offtake certificates or contracts for difference. In both cases,
 
Equinor and
its partners take the risk for developing, constructing and operating the wind farms within a fixed
 
timeframe.
Taxation of Equinor
Norway
Equinor’s profits, both from offshore oil and natural gas activities and from onshore activities, are
 
subject to Norwegian corporate
income tax. In addition, a special petroleum tax is levied on profits from petroleum production
 
and pipeline transportation on the NCS.
In June 2022 the parliament enacted a cash-flow based tax system for the special petroleum tax
 
with effect from 1 January 2022.
After the reform, the standard corporate income tax rate is 22% and the special petroleum tax rate
 
is 71.8%. The corporate tax is
deductible in the basis for the special petroleum tax, resulting in a 78% marginal tax rate.
 
For further information,
 
see note 11 Income
taxes to the Consolidated Financial Statements.
Investment costs in the ordinary tax base (22%) will continue to be depreciated over six years. In
 
the special tax base,
investments are written off immediately in line with the cash-flow based tax system. Projects covered by the temporary rules
introduced in 2020 have had a tax uplift of 17.69% in 2022. In 2023 the tax uplift is reduced to
 
12.4%. The temporary rules apply to
investments covered by field or infrastructure plans (PDOs and PIOs) submitted to the MPE
 
after 12 May 2020 and before 1 January
2023 and approved before 1 January 2024. The temporary rules will continue to apply until (and
 
including) the year of planned
production or project start-up according to the approved plans.
Equinor’s international petroleum activities are subject to tax pursuant to local legislation.
US
Equinor’s operations in the US are subject generally to corporate income, severance
 
and production, ad valorem and transaction
taxes levied by the federal, state and local tax authorities, and to royalties payable to federal,
 
state and local authorities and, in some
cases, private landowners. The federal corporate income tax rate in the US is 21%, and there is an alternative 15% minimum
 
tax on
corporate book income for corporations with profits over USD 1 billion, effective for tax years beginning after 31 December
 
2022.
Brazil
Corporate income tax and social contribution are levied on taxable net income at a combined rate of 34%. A
 
simplified tax regime
with a lower effective tax rate is available for legal entities with gross revenues below a threshold of 78 million
 
Brazilian reais per year.
In addition, there are several indirect taxes but exports are exempt. In January 2023 a new President
 
takes office and new rounds of
discussions around certain tax proposals are expected to occur, such as creation of withholding tax on dividends and an export tax for
crude oil, among other proposals.
Imports of assets are subject to several customs duties, but a special regime is available for certain assets
 
used in the oil and gas
activities allowing suspension of the federal duties and reduction of state duties.
The concession regime usually includes a 10% royalty, and special participation tax that varies based on time, location and
production between 10% and 40%. PSA regime usually includes a 15% royalty, an annual 80% cost recovery ceiling, and a biddable
government profit share.
Disclosures regarding oil and gas operations
Exhibit 15.5 to this 2022 Form 20-F is incorporated herein by reference. See also notes 5
 
Segments and 7 Total revenues and
other income to the Consolidated financial statements.
The information set forth under the headings “Operational data”, “Sales volumes” and “Sales prices” in
 
Section 2.2 of Chapter 2
on pages 75-77, “Unit Production Cost (UPC)” in Section 2.2.1 of Chapter 2 on page
 
82, and “Optimised oil and gas portfolio” in
Section 3.1 of Chapter 3 on pages 111-115
 
of the 2022 Annual Report is also incorporated herein by reference.
Supplementary oil and gas information pursuant to FASB Topic 932
The following information is reported pursuant to FASB Topic 932.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Capitalised cost related to oil and gas producing
 
activities
Consolidated companies
At 31 December
(in USD million)
2022
2021
2020
Unproved properties
5,917
7,077
9,034
Proved properties, wells, plants and other equipment
181,189
193,918
194,655
Total capitalised cost
187,106
200,994
203,690
Accumulated depreciation, impairment and amortisation
(133,584)
(139,890)
(136,524)
Net capitalised cost
53,523
61,104
67,165
Net capitalised cost related to equity accounted investments as of 31 December 2022 was USD
 
463 million, USD 900 million in 2021
and USD 450 million in 2020. The reported figures are based on capitalised costs within the
 
upstream segments in Equinor, in line
with the description below for result of operations for oil and gas producing activities.
Expenditures incurred in oil and gas property acquisition,
 
exploration and development activities
These expenditures include both amounts capitalised and
 
expensed.
Consolidated companies
(in USD million)
Norway
Eurasia
excluding
Norway
Africa
USA
Americas
excluding
USA
Total
Full year 2022
Exploration expenditures
494
27
57
150
360
1,088
Development costs
4,483
320
379
712
965
6,859
Acquired proved properties
110
226
38
0
0
374
Acquired unproved properties
6
0
0
0
0
6
Total
5,093
573
474
862
1,325
8,327
Full year 2021
Exploration expenditures
522
61
5
139
299
1,026
Development costs
4,732
322
256
605
977
6,892
Acquired proved properties
3
5
0
0
0
8
Acquired unproved properties
6
9
1
24
(3)
37
Total
5,263
397
262
768
1,273
7,963
Full year 2020
Exploration expenditures
470
197
81
215
409
1,372
Development costs
4,466
436
279
983
565
6,729
Acquired proved properties
0
0
36
7
0
43
Acquired unproved properties
0
41
2
1
24
68
Total
4,936
674
398
1,206
998
8,212
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Expenditures incurred in exploration and development activities related to equity accounted investments was USD
 
155 million in 2022,
USD 233 million in 2021 and USD 71 million in 2020.
Results of operation for oil and gas producing activities
As required by Topic 932, the revenues and expenses included in the following table reflect only those relating to the oil and gas
producing operations of Equinor.
The results of operations for oil and gas producing activities are included in the two upstream reporting segments
 
Exploration &
Production Norway (E&P Norway) and Exploration & Production International (E&P International)
 
as presented in note 5 Segments
to
the Consolidated financial statements. Production cost is based on operating expenses related to
 
production of oil and gas. From the
operating expenses certain expenses such as; transportation costs, accruals for over/underlift position and royalty payments
 
costs are
excluded. These expenses and mainly upstream business administration are included as other
 
expenses in the tables below. Other
revenues mainly consist of gains and losses from sales of oil and gas interests and gains
 
and losses from commodity-based
derivatives within the upstream segments.
Income tax expense is calculated on the basis of statutory tax rates adjusted for uplift and tax credits.
 
No deductions are made for
interest or other elements not included in the table below.
Consolidated companies
(in USD million)
Norway
Eurasia
excluding
Norway
Africa
USA
Americas
excluding
USA
Total
Full year 2022
Sales
155
554
615
166
88
1,578
Transfers
74,468
1,252
3,019
5,168
1,853
85,760
Other revenues
1,308
(203)
(1)
213
57
1,374
Total revenues
75,931
1,603
3,633
5,547
1,998
88,712
Exploration expenses
(366)
(249)
(69)
(220)
(320)
(1,224)
Production costs
(2,916)
(202)
(470)
(399)
(518)
(4,505)
Depreciation, amortisation and net impairment losses
(4,167)
(623)
(530)
(361)
(579)
(6,260)
Other expenses
(866)
(201)
3
(533)
(413)
(2,010)
Total costs
(8,315)
(1,275)
(1,066)
(1,513)
(1,830)
(13,999)
Results of operations before tax
67,616
328
2,567
4,034
168
74,713
Tax expense
(52,070)
(152)
(1,043)
2,458
361
(50,447)
Results of operations
15,546
176
1,524
6,492
529
24,266
Net income/(loss) from equity accounted investments
0
52
0
0
120
172
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Consolidated companies
(in USD million)
Norway
Eurasia
excluding
Norway
Africa
USA
Americas
excluding
USA
Total
Full year 2021
Sales
97
476
638
207
16
1,434
Transfers
38,578
960
2,021
3,712
1,249
46,520
Other revenues
711
(14)
0
221
14
932
Total revenues
39,386
1,422
2,659
4,140
1,279
48,886
Exploration expenses
(363)
(108)
23
(211)
(362)
(1,021)
Production costs
(2,600)
(196)
(497)
(397)
(378)
(4,068)
Depreciation, amortisation and net impairment losses
(4,900)
(2,462)
(444)
(1,734)
(416)
(9,956)
Other expenses
(1,052)
(140)
53
(674)
(292)
(2,105)
Total costs
(8,915)
(2,906)
(865)
(3,016)
(1,448)
(17,150)
Results of operations before tax
30,471
(1,484)
1,794
1,124
(169)
31,736
Tax expense
(22,887)
835
(652)
(14)
(201)
(22,919)
Results of operations
7,585
(649)
1,142
1,110
(370)
8,817
Net income/(loss) from equity accounted investments
0
176
0
0
39
215
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Consolidated companies
(in USD million)
Norway
Eurasia
excluding
Norway
Africa
USA
Americas
excluding
USA
Total
Full year 2020
Sales
76
189
240
218
5
728
Transfers
11,778
652
1,621
2,181
910
17,142
Other revenues
165
14
0
216
5
400
Total revenues
12,019
855
1,861
2,615
920
18,270
Exploration expenses
(423)
(295)
(1,034)
(1,000)
(739)
(3,491)
Production costs
(2,048)
(192)
(440)
(563)
(376)
(3,619)
Depreciation, amortisation and net impairment losses
(5,727)
(2,081)
(737)
(3,827)
(713)
(13,085)
Other expenses
(688)
(150)
(56)
(753)
(220)
(1,867)
Total costs
(8,886)
(2,718)
(2,267)
(6,143)
(2,048)
(22,062)
Results of operations before tax
3,133
(1,863)
(406)
(3,528)
(1,128)
(3,792)
Tax expense
(1,429)
718
(168)
(30)
(252)
(1,159)
Results of operations
1,704
(1,145)
(574)
(3,558)
(1,380)
(4,951)
Net income/(loss) from equity accounted investments
0
(136)
0
0
(10)
(146)
Average production cost in USD per boe
 
based on entitlement
volumes (consolidated)
Norway
Eurasia
excluding
Norway
Africa
USA
Americas
excluding
USA
Total
2022
6
13
12
4
21
7
2021
5
11
12
3
19
6
2020
4
10
9
4
14
5
Production cost per boe is calculated as the production costs in the result of operations table, divided
 
by the produced entitlement
volumes (mboe) for the corresponding period.
C.
 
Organizational Structure
Exhibit 8 to this 2022 Form 20-F is incorporated herein by reference.
D.
 
Property, Plant and Equipment
Equinor has interests in real estate in many countries throughout the world,
 
including as part of certain developments and
projects of Equinor or in which Equinor participates.
Equinor’s largest office buildings are (i) its head office located at Forusbeen 50, Stavanger, Norway which comprises
approximately 135,000 square meters of office space, (ii) its office building in Sandslivegen 90, Bergen, Norway which comprises
approximately 99,488 square meters of office space, and (iii) its office building located at Fornebu on the outskirts of Oslo which
comprises approximately 65,500 square meters. All three office buildings are leased by Equinor. Under a new lease agreement
entered into in 2022 for the office building at Fornebu, Equinor has reduced its area to 44,500 square
 
meters with effect from around
the start of year 2024. The office building in Bergen is owned by Sandsliveien 90 AS, a subsidiary
 
of Equinor Pensjon.
The information set forth under the following headings of the 2022 Annual Report is incorporated herein by reference:
●
 
Investments in Section 2.2.2 of Chapter 2 on pages 87 – 88;
●
 
Exploration & Production Norway in Section 3.1.1 of Chapter 3 on pages 116 – 124;
●
 
Exploration & Production International in Section 3.1.2 of Chapter 3 on pages 125 – 131;
●
 
Exploration & Production USA in Section 3.1.3 of Chapter 3 on pages 132 – 135;
●
 
High-value growth in renewables in Section 3.2 of Chapter 3 on pages 136 – 139;
●
 
Marketing, midstream and processing (MMP), including new market opportunities in low carbon
 
solutions in
Section 3.3 of Chapter 3 on pages 140 – 148; and
●
 
Production per field in Section 5.5 of Chapter 5 on pages 297 – 301.
See also notes 12 Property, plant and equipment and 25 Leases to the Consolidated financial statements
ITEM 4A. UNRESOLVED STAFF COMMENTS
Not applicable.
ITEM
 
5. OPERATING AND FINANCIAL REVIEW AND PROSPECTS
The discussion does not address certain items in respect of 2020. A discussion of
 
such items may be found in the Annual Report
on Form 20-F for the year ended 31 December, 2021, filed with the SEC 18 March 2022.
A.
 
Operating Results
The information set forth under the following headings of the 2022 Annual Report is incorporated
 
herein by reference:
●
 
Group Analysis in Section 2.2 of Chapter 2 on pages 70 – 74;
●
 
Group outlook in Section 2.2 of Chapter 2 on page 74;
●
 
Efficient and predictable operations in Section 2.2.1 of Chapter 2 on pages 80 – 82;
●
 
Contextual Introduction, Management approach, Physical Climate Risk and Performance Disclosure
 
in Section
2.2.2 of Chapter 2 on pages 83 – 87;
●
 
Return on average capital employed (ROACE), Relative ROACE (peer group rank) and Relative
 
TSR in Section
2.2.2 of Chapter 2 on pages 88 – 89;
●
 
Net zero pathway in Section 2.3.1 of Chapter 2 on pages 100 – 103;
●
 
Emissions reductions in Section 2.3.2 of Chapter 2 on pages 104 – 108;
●
 
Reporting Segment Performance in Chapter 3 on pages 110 – 111;
●
 
Performance review in Section 3.1.1 of Chapter 3 on pages 118 – 119;
●
 
Performance review in Section 3.1.2 of Chapter 3 on pages 126 – 127;
●
 
Performance review in Section 3.1.3 of Chapter 3 on pages 132 – 133;
●
 
Performance review in Section 3.2 of Chapter 3 on pages 138 – 139;
●
 
Performance review in Section 3.3 of Chapter 3 on pages 146 – 148; and
●
 
Performance review in Section 3.4 of Chapter 3 on page 149.
See also the information set forth under the heading “Applicable Laws and Regulations” in “Item 4―Information
 
on the
Company―B. Business Overview” of this 2022 Form 20-F, and note 3 Consequences of inititiatives to limit climate changes to the
Consolidated financial statements.
B.
 
Liquidity and capital resources
The information set forth under the following headings of the 2022 Annual Report is incorporated herein by reference:
●
 
Capital and liquidity management in Section 1.6 of Chapter 1 on pages 30 – 31, excluding the
 
information in the
second and sixth paragraphs under the sub-heading “Debt and Credit Rating”;
 
and
●
 
Review of cash flows and Balance sheet and financial indicators in Section 2.2 of Chapter
 
2 on pages 72 – 73; and
●
 
Investments in Section 2.2.2 of Chapter 2 on pages 87 – 88.
Any credit rating referred to in this 2022 Form 20-F is not a recommendation to buy, hold or sell any of our or our subsidiaries’
securities. Credit ratings may be changed, suspended or withdrawn at any time, and each rating
 
should be evaluated independently of
any other rating.
Equinor expects to complete the transition from London Inter-bank Offered Rates (LIBOR) to alternative reference
 
rates within
2023. For interest rate derivatives contracts, Equinor in general follows the ISDA Fallback Protocol
 
outlining the process for
conversion of LIBOR to the Official ISDA Fallback Rates for derivatives, or other official adjusted reference rates (such as SONIA
 
or
SOFR). The transition from LIBOR to alternative reference rates for floating rate bonds
 
follows in general the principles outlined by
ICMA (International Capital Markets Association) and loan agreements and facilities in general
 
follows the LMA (Loan Market
Association). Equinor believes that the financial risks for Equinor related to the transition
 
are small.
See also notes 18 Trade and other receivables, 19 Cash and cash equivalents, 21 Finance debt, 23 Provisions
 
and other
liabilities, 24 Trade, other payables
 
and provisions, 25 Leases, and 26 Other commitments, contingent liabilities and contingent
 
assets
to the Consolidated financial statements.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Principal contractual obligations
The following table summarises principal contractual obligations, excluding derivatives and other hedging instruments,
 
as well as
asset retirement obligations which for the most part are expected to lead to cash disbursements
 
more than five years into the future.
See note 23 for a maturity profile on asset retirement obligations and other provisions.
Non-current finance debt in the table represents principal payment obligations, including interest obligation. Obligations
 
payable by
Equinor to entities accounted for in the Equinor group using the equity method are included in
 
the table below with Equinor’s full
proportionate share. For assets that are included in the Equinor accounts through joint
 
operations or similar arrangements, the
amounts in the table include the net commitment payable by Equinor (i.e., Equinor’s proportionate
 
share of the commitment less
Equinor's ownership share in the applicable entity).
Principal contractual obligations
As at 31 December 2022
Payment due by period
1)
(in USD million)
Less than 1
year
1-3 years
3-5 years
More than 5
years
Total
Undiscounted non-current finance debt- principal and
 
interest
2)
3,147
6,292
5,785
19,953
35,177
Undiscounted leases
3)
1,325
1,421
504
585
3,835
Nominal minimum other long-term commitments
4)
2,603
3,995
2,569
5,733
14,900
Total contractual obligations
7,075
11,708
8,858
26,271
53,912
1)
''Less than 1 year'' represents 2023; ''1-3 years''
 
represents 2024 and 2025, ''3-5 years'' represents
 
2026 and 2027, while ''More than 5
years'' includes amounts for later periods.
2)
See note 21 Finance debt to the Consolidated
 
financial statements. The main differences between the table
 
and the note relate to
interest.
 
3)
See note 4 Financial risk management to the Consolidated
 
financial statements.
4)
See note 26 Other commitments and contingencies
 
to the Consolidated financial statements.
Equinor had contractual commitments of USD 5,454 million at 31 December 2022. The contractual commitments
 
reflect Equinor's
share and mainly comprise construction and acquisition of property, plant and equipmentas well as committed investments/funding or
resources in equity accounted entities.
Equinor’s projected pension benefit obligation was USD 7,670 million, and the fair value
 
of plan assets amounted to USD 5,218 million
as of 31 December 2022. The company’s payments regarding these benefit plans are mainly related to employees
 
in Norway. See
note 22 Pensions to the Consolidated financial statements for more information.
Off balance sheet arrangements
Equinor is party to various agreements such as transportation and processing capacity contracts, that are
 
not recognised in the
balance sheet. Furthermore, Equinor is lessee in a range of lease contracts, whereas
 
all leases shall be recognised in the balance
sheet. Commitments regarding the non-lease components of lease contracts as well as leases
 
that have not yet commenced are not
recognised in the balance sheet and represent off balance sheet commitments. Equinor is also party to certain guarantees,
commitments and contingencies that, pursuant to IFRS, are not necessarily recognised in the balance
 
sheet as liabilities. See note 26
Other commitments and contingencies
to the Consolidated financial statements for more information.
Summarised financial information related to guaranteed debt securities
The following summarised financial information provides financial information of Equinor Energy AS
 
as co-obligor and guarantor
as required by SEC Rule 3-10 and 13-01 of Regulation S-X.
Equinor Energy AS is a 100% owned subsidiary of Equinor ASA. Equinor Energy AS is the
 
co-obligor of certain existing debt
securities of Equinor ASA and has guaranteed certain existing debt securities of Equinor ASA,
 
including in each case debt securities
that are registered under the US Securities Act of 1933 ("US registered debt securities").
As co-obligor, Equinor Energy AS fully, unconditionally and irrevocably assumes and agrees to perform, jointly and severally with
Equinor ASA, the payment and covenant obligations for certain debt held by Equinor ASA.
 
As a guarantor, Equinor Energy AS fully
and unconditionally guarantees the payment obligations for certain debt held by Equinor ASA. Total debt at 31 December 2022 is
USD 26,683 million, all of which is either guaranteed by Equinor Energy AS (USD 24,540 million),
 
or for which Equinor Energy AS is
co-obligor (USD 2,143 million). In the future, Equinor ASA may from time to time issue
 
debt for which Equinor Energy AS will be the
co-obligor or guarantor.
The applicable US registered debt securities and related guarantees of Equinor Energy AS are
 
unsecured and rank equally with all
other unsecured and unsubordinated indebtedness of Equinor ASA and Equinor Energy AS. The
 
guarantees of Equinor Energy AS
are subject to release in limited circumstances upon the occurrence of certain customary conditions.
 
With respect to US registered
debt securities (and certain other debt securities) issued on or after 18 November 2019, Equinor
 
Energy AS will automatically and
unconditionally be released from all obligations under its guarantee and the guarantee shall
 
thereupon terminate and be discharged of
no further force or effect, in the event that at substantially the same time as its guarantee of such
 
debt securities is terminated, the
aggregate amount of indebtedness for borrowed money for which Equinor Energy AS is
 
an obligor (as a guarantor, co-issuer or
borrower) does not exceed 10% of the aggregate principal amount of indebtedness for borrowed
 
money of Equinor ASA and its
subsidiaries, on a consolidated basis, as of such time.
Internal dividends, group contributions and repayment of capital from Equinor Energy AS to Equinor
 
ASA are regulated in the
Norwegian Public Limited Liabilities Act §§ 3-1 - 3-5.
 
The following summarised financial information for the year ended 31 December 2022 provides
 
financial information about Equinor
ASA, as issuer, and Equinor Energy AS, as co-obligor and guarantor on a combined basis after elimination of transactions between
Equinor ASA and Equinor Energy AS. Investments in non-guarantor subsidiaries are eliminated.
 
Currency gain on transactions
between Equinor ASA and Equinor Energy AS of USD 4,607 million is included in
 
financial items in accordance with the IFRS group
accounting principles and are included in external items in the Condensed profit
 
and loss statement.
Intercompany balances and transactions between the obligor group and the non-guarantor subsidiaries are
 
presented on separate
lines. Transactions with related parties are also presented on a separate line item and include transactions with the Norwegian
 
State's
and the Norwegian State’s share of dividend declared but not paid.
The combined summarized financial information is prepared in accordance with Equinor's IFRS
 
accounting policies as described in
note 2 Significant accounting policies to the Consolidated financial statements.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
COMBINED PROFIT AND LOSS STATEMENT FOR EQUINOR ASA AND EQUINOR ENERGY AS
Full year 2022
(unaudited, in USD million)
Revenues and other income
 
137,153
 
External
 
122,110
 
Non-guarantor subsidiaries
 
14,649
 
Related parties
 
394
 
Operating expenses
 
(58,328)
External (incl depreciation)
 
(31,245)
Non-guarantor subsidiaries
 
(12,971)
Related parties
 
 
(14,112)
Net operating income
 
78,825
 
Net financial items
 
1,118
 
External
 
(115)
Non-guarantor subsidiaries
 
1,233
 
Related parties
-
Income before tax
 
79,943
 
Income tax
 
(51,197)
Net income
 
28,746
 
COMBINED BALANCE SHEET FOR EQUINOR ASA AND EQUINOR ENERGY
 
AS
At 31 December
 
(unaudited, in USD million)
2022
Non-current assets
 
49,422
 
External
 
35,398
 
Non-guarantor subsidiaries
 
12,505
 
Related parties
 
1,519
 
Current assets
 
64,426
 
External
 
57,912
 
Non-guarantor subsidiaries
 
6,336
 
Related parties
 
178
 
Non-current liabilities
 
53,935
 
External
 
52,107
 
Non-guarantor subsidiaries
 
139
 
Related parties
 
1,689
 
Current liabilities
 
53,010
 
External
 
30,550
 
Non-guarantor subsidiaries
 
21,402
 
Related parties
 
1,058
 
C. Research and development, Patents and Licences, etc.
The information set forth under the following headings of the 2022 Annual Report is incorporated herein by reference:
●
 
Technology development in Section 1.3 of Chapter 1 on page 21; and
●
 
Research and development in Section 1.5 of Chapter 1 on page 29.
See also notes 9 Auditor’s remuneration and Research and development
 
expenditures and 12 Property, plant and equipment to
the Consolidated financial statements.
D.
 
Trend information
The information set forth under the heading “
Equinor’s market perspective
” in Section 1.4 of Chapter 1 on pages 23 – 24 of the
2022 Annual Report is incorporated herein by reference. See also “Item 5. Operating and Financial
 
Review―A. Operating Results” of
this 2022 Form 20-
F.
E.
 
Critical Accounting Estimates
Not Applicable.
ITEM 6. DIRECTORS, SENIOR MANAGEMENT AND EMPLOYEES
A.
 
Directors and Senior Management
Members of Equinor’s board of directors as of 31 December 2022:
Jon Erik Reinhardsen
Born
: 1956
Position
: Shareholder-elected chair of the board and chair of the board's compensation and executive development committee.
Term
of office
: Chair of the board of Equinor ASA since 1 September 2017. Up for election in 2023.
Independent
: Yes
Other
directorships
:
Listed companies: Member of the board of Oceaneering International, Inc. and Telenor ASA.
Non-listed companies: Member of the board of Awilhelmsen AS and Bico bygg og Innredning AS and chair of the
 
board of Fire
Security AS.
Number of shares in Equinor ASA as of 31 December 2022
: 4,584
Loans from Equinor
: None
Experience
: Reinhardsen is a part-time senior advisor with BearingPoint Capital. Reinhardsen was
 
the Chief Executive Officer of
Petroleum Geo-Services (PGS) from 2008 - 2017. PGS delivers global geophysical-
 
and reservoir services. In the period 2005 -
2008 Reinhardsen was President Growth, Primary Products in the international aluminium
 
company Alcoa Inc. with headquarters
in the US, and he was in this period based in New York. From 1983 - 2005, Reinhardsen held various positions in the Aker
Kværner group, including Group Executive Vice President of Aker Kværner ASA, Deputy Chief
 
Executive Officer and Executive
Vice President of Aker Kværner Oil & Gas AS in Houston and Executive Vice President in Aker Maritime ASA.
Education
: Master’s degree in Applied Mathematics and Geophysics from the
 
University of Bergen. He has also attended the
International Executive Program at the Institute for Management Development (IMD) in Lausanne, Switzerland.
Family relations:
 
No family relations to other members of the board, members of the corporate executive
 
committee or the
corporate assembly.
Other matters
: In 2022, Reinhardsen participated in eight ordinary board meetings, four extraordinary board
 
meetings, six
meetings of the compensation and executive development committee and two meetings of the audit committee.
 
Reinhardsen is a
Norwegian citizen and resident in Norway.
Anne Drinkwater
Born
: 1956
Position
: Shareholder-elected deputy chair of the board, chair of the board’s audit committee and member of the board’s safety,
sustainability and ethics committee.
Term of office
: Member of the board of Equinor ASA since 1 July 2018, deputy chair of the board
 
since 1 July 2022. Up for
election in 2023.
Independent:
 
Yes
Other directorships:
Listed company: Non-executive member of the board of Balfour Beatty plc.
Number of shares in Equinor ASA
as of 31 December 2022
: 1,100
Loans from Equinor:
 
None
Experience:
Drinkwater was employed with bp in the period 1978 - 2012, holding a number of different leadership positions in
the company. In the period 2009 - 2012 she was chief executive officer of bp Canada. She has extensive international
experience, including being responsible for operations in the US, Norway, Indonesia, the Middle East and Africa. Through her
career Drinkwater has acquired a deep understanding of the oil and gas sector, holding both operational roles, and more distinct
business responsibilities.
Education:
Bachelor of Science in Applied Mathematics and Statistics, Brunel University London.
Family relations:
No family relations to other members of the board, members of the corporate executive
 
committee or the
corporate assembly.
Other matters:
 
In 2022, Drinkwater participated in eight ordinary board meetings, four extraordinary board meetings, six
meetings of the audit committee and five meetings of the safety, sustainability and ethics committee. Drinkwater is a British
citizen and resident in the US.
Rebekka Glasser Herlofsen
Born:
 
1970
Position:
 
Shareholder-elected member of the board, the board's audit committee and the board’s compensation and executive
development committee.
Term of office
: Member of the board of Equinor ASA since 19 March 2015. Up for election in
 
2023.
Independent:
 
Yes
Other directorships:
Listed companies: Member of the board of SATS ASA, Rockwool International A/S, BW Offshore ASA and Wilh. Wilhelmsen
Holding ASA.
Non-listed companies: Chair of the Board of Norwegian Hull Club (NHC) and Handelsbanken
 
Norge, and board member of
Torvald Klaveness Group.
Number of shares in Equinor ASA as of 31 December 2022
:
220
Loans from Equinor ASA:
 
None
Experience:
 
Herlofsen is an independent board member and consultant. She was previously
 
the Chief Financial Officer in
Wallenius Wilhelmsen ASA, an international shipping company. Before joining Wallenius Wilhelmsen, she was the Chief
Financial Officer in the shipping company Torvald Klaveness since 2012. She has broad financial and strategic experience from
several corporations and board directorships. Herlofsen’s professional career began in the Nordic Investment Bank, Enskilda
Securities, where she worked with corporate finance from 1995 to 1999 in Oslo and London. During
 
the next ten years Herlofsen
worked in the Norwegian shipping company Bergesen d.y. ASA (later BW Group). During her period with Bergesen d.y. ASA/BW
Group she held leading positions within M&A, strategy and corporate planning and was
 
part of the group management team.
Education:
 
MSc in Economics and Business Administration (“Siviløkonom”) and Certified Financial
 
Analyst Program (AFA), the
Norwegian School of Economics (NHH). Breakthrough Program for Top Executives at IMD business school, Switzerland.
Family relations:
 
No family relations to other members of the Board, members of the Corporate
 
Executive Committee or the
Corporate Assembly.
Other matters:
 
In 2022, Herlofsen participated in eight ordinary board meetings, four extraordinary
 
board meetings, three
meetings of the compensation and executive development committee and six meetings of the audit
 
committee. Herlofsen is a
Norwegian citizen and resident in Norway.
Jonathan Lewis
Born
: 1961
Position
: Shareholder-elected member of the board,
 
chair of the board’s safety, sustainability and ethics committee and member of the
board’s audit committee.
Term of office
: Member of the board of Equinor ASA since 1 July 2018. Up for election
 
in 2023.
Independent
: Yes
Other directorships
:
Listed company: Member of the board of Capita plc.
Number of shares in Equinor ASA as of 31 December 2022
: None
Loans from Equinor
: None
Experience
: Lewis joined Capita as its chief executive officer (CEO) in December 2017; having previously spent
 
30 years
working for large multi-national companies in technology-enabled industries. Lewis came to Capita
 
plc from Amec Foster Wheeler
plc, a global consulting, engineering and construction company, where he was CEO from 2016 - 2017. Prior to this, he held a
number of senior leadership positions at Halliburton, where he was employed in the period
 
1996 - 2016. Lewis has previously
held several directorships within technology and the oil and gas industry.
Education:
Lewis has a PhD in Reservoir Characterisation from University of Reading and a Bachelor of Science
 
degree in
Geology from Kingston University.
Family relations
: No family relations to other members of the board, members of the corporate executive committee
 
or the
corporate assembly.
Other matters:
 
In 2022, Lewis participated in eight ordinary board meetings, four extraordinary board meetings, three
 
meetings
of the compensation and executive development committee, five meetings of the audit committee and five meetings
 
of the safety,
sustainability and ethics committee. Lewis is a British and US citizen, and resident in the UK.
Finn Bjørn Ruyter
Born
: 1964
 
Position
: Shareholder-elected member of the board and member of the board’s audit committee and the board’s compensation
and executive development committee.
Term of office
: Member of the board of Equinor ASA since 1 July 2019. Up for election
 
in 2023.
Independent
: Yes
Other directorships
:
Non-listed companies: Chair of the board of Fornybar Norge AS and board member of Cegal Sysco
 
AS, in addition to several
companies fully or partly owned by Hafslund.
Number of shares in Equinor ASA as of 31 December 2022
: 620
Loans from Equinor
: None
Experience
: Ruyter has since July 2012
 
been chief executive officer (CEO) of Hafslund AS. He was chief financial officer (CFO)
in the company from 2010 - 2011. In 2009 - 2010 he worked in the Philippine hydro power company SN Aboitiz Power. In the
period 1996 - 2009 he led the power trading entity and from 1999 also the energy division in Elkem.
 
From 1991 - 1996 Ruyter
worked with energy trading in Norsk Hydro.
Education:
Master’s degree in Mechanical Engineering from the Norwegian University
 
of Technology (NTNU) and an MBA from
BI Norwegian School of Management.
Family relations
: No family relations to other members of the board, members of the corporate executive committee
 
or the
corporate assembly.
Other matters:
 
In 2022, Ruyter participated in eight ordinary board meetings, four extraordinary board meetings, six meetings
 
of
the audit committee and six meetings of the compensation and executive development committee. Ruyter
 
is a Norwegian citizen
and resident in Norway.
Tove Andersen
Born
: 1970
Position
: Shareholder-elected member of the board and the board’s safety, sustainability and ethics committee.
Term of office
: Member of the board of Equinor ASA since 1 July 2020.
 
Up for election in 2023.
Independent
: Yes
Other directorships
:
Listed company: Member of the board of Borregaard ASA.
Number of shares in Equinor ASA as of 31 December 2022
: 4,700
Loans from Equinor:
 
None
Experience
: Andersen is President & CEO of Tomra Systems ASA as of 16 August 2021. Prior to this, she held the position as
executive vice president for Europe in Yara International ASA. Andersen was part of the executive management team in Yara
since 2016 where she also held positions as executive vice president, Production and executive vice president,
 
Supply Chain.
Previously she has had several management roles within Yara and Norsk Hydro/Yara and she started in Norsk Hydro in 1997.
She has extensive international industrial experience, and she has broad board experience.
Education
: Master of Science (Sivilingeniør) from Norwegian Institute of Technology (NTNU) and a Master of Business
Administration from the BI Norwegian Business School.
Family relations
: No family relations to other members of the board, members of the corporate executive committee
 
or the
corporate assembly.
Other matters
: In 2022, Andersen participated in eight ordinary board meetings, three extraordinary
 
board meetings, two
meetings of the compensation and executive development committee and two meetings of the
 
board’s safety, sustainability and
ethics committee. Andersen is a Norwegian citizen and resident in Norway.
Michael D. Lewis
Born:
 
1967
Position:
 
Shareholder-elected member of the board and the board’s compensation and executive development
 
committee.
Term of office:
Member of the board of Equinor ASA since 1 July 2022. M. Lewis resigned
 
from his position as member of the
board of directors in Equinor ASA with effect as of 16 March 2023.
Independent:
Yes
Other directorships:
Non-listed companies: Member of the Natural Environment Research Council (NERC) and the
 
board of Energy UK.
Number of shares in Equinor ASA as of 31 December 2022
:
None
 
Loans from Equinor ASA:
None
Experience:
Lewis joined as CEO to E.ON UK plc in 2017; having previously held the position
 
as CEO of E.ON Climate &
Renewables GmbH in the period 2015-2017 and Chief Operating Officer in the same company from
 
2007-2015. He held the role
as Vice President Corporate Strategy in E.ON AG from 2004-2007. Lewis has also worked as Equity Analyst,
 
Strategy Analyst
and Environmental Specialist and Environmental Scientist in other companies. Lewis has extensive
 
international experience and
broad board experience.
Education:
Lewis holds an MA in Environmental Law from De Montfort University, MSc Pollution and Environmental Control from
the University of Manchester and BEng (Hons) Engineering Technology from Leicester Polytechnic. He is a Chartered Engineer
(CEng) and a Fellow of the Institution of Mechanical Engineers (FIMechE).
Family relations:
No family relations to other members of the board, members of the corporate executive
 
committee or the
 
corporate assembly.
Other matters:
 
In 2022, Lewis participated in four ordinary board meetings, one extraordinary board meetings and three
meetings of the compensation. Lewis is a dual British/German citizen, and currently resident in the
 
UK.
Haakon Bruun-Hanssen
Born:
1960
Position:
 
Shareholder-elected member of the board, the board's compensation and executive development
 
committee and the
board's safety, sustainability and ethics committee.
Term of office:
Member of the Board of Equinor ASA since 12 December 2022. Up for election
 
in 2023.
Independent:
Yes
Other directorships:
Non-listed companies: Member of the Advisory Board at Kongsberg Defence & Aerospace (KDA) and
 
Dolphitech
Number of shares in Equinor ASA as of 31 December 2022
: None
 
Loans from Equinor ASA:
None
Experience:
Bruun-Hanssen held the position as Chief of Norwegian Defence Forces from 2013-2020,
 
previously having held
the position as Chief Norwegian Joint Operational Headquarters from 2011-2013 and Chief Royal Norwegian Navy from 2009-
2011, Chief of staff Royal Norwegian Navy from 2007-2009 and Chief Naval Operations centre from 2003-2007. Prior to this he
has had an extensive career in the Norwegian Military.
Education:
Bruun-Hanssen has a broad education through the Norwegian Military; Petty Officer training school, Norwegian naval
Academy, Submarine Commanding officer course and Higher command course, Forsvarets Høyskole. He is also educated at
Military Command and Staff college, Instituut Defensie Leergangen in The Netherlands and has participated in work
 
sessions
relating to board roles and tasks at Insead In-Board Nordic Academy.
Family relations:
No family relations to other members of the board, members of the corporate executive
 
committee or the
corporate assembly.
Other matters:
Bruun-Hanssen is a Norwegian citizen, and resident in Norway.
Stig Lægreid
Born
: 1963
Position:
Employee-elected member of the board and member of the board's safety, sustainability and ethics committee.
Term of office:
Member of the board of Equinor ASA since 1 July 2013. Up for election
 
in 2023.
Independent:
No
Other directorships
: None
Number of shares held in Equinor ASA as of 31 December 2022
: 5
Loans from Equinor
: None
Experience:
Lægreid is now a full-time employee representative as the leader of NITO, Equinor. He has been occupied as
weight estimator for platform design from 2005 and prior to this as project engineer and constructor
 
for production of primary
metals. Employed in ÅSV and Norsk Hydro since 1985.
Education
: Bachelor’s degree, Mechanical Construction from Oslo college of engineering
 
(OIH).
Family relations:
No family relationships to other board members, members of the corporate executive committee
 
or the
corporate assembly.
Other matters
: In 2022, Lægreid participated in eight ordinary board meetings, four extraordinary board meetings
 
and five
meetings of the safety, sustainability and ethics committee. Lægreid is a Norwegian citizen and resident in Norway.
Per Martin Labråten
 
Born:
 
1961
Position:
 
Employee-elected member of the board, and member of the board’s compensation and executive development
committee and the board’s safety, sustainability and ethics committee.
Term of office:
 
Member of the board of Equinor ASA since 8 June 2017. Up for election
 
in 2023.
Independent:
 
No
Other directorships:
 
Labråten is a member of the executive committee of the Industry Energy (IE) trade union and
 
holds a
number of positions as a result of this.
Number of shares in Equinor ASA as of 31 December 2022
:
587
Loans from Equinor:
 
None
Experience:
 
Labråten is now a full-time employee representative as the leader of IE Equinor branch. He
 
has previously worked
as a process technician at the petrochemical plant on Oseberg field in the North Sea.
Education:
Labråten has a craft certificate as a process/chemistry worker.
Family relations:
 
No family relations to other members of the board, members of the corporate executive
 
committee or the
corporate assembly.
Other matters:
 
In 2022, Labråten participated in eight ordinary board meetings, four extraordinary board meetings,
 
four meetings
of the compensation and executive development committee and five meetings of the safety, sustainability and ethics committee.
Labråten is a Norwegian citizen and resident in Norway.
Hilde Møllerstad
Born:
1966
Position:
Employee-elected member of the board and member of the board's audit committee.
Term of office:
Member of the board of Equinor ASA since 1 July 2019. Up for election
 
in 2023.
Independent:
No
Other directorships:
Chair of Tekna’s ethical board.
Number of shares held in Equinor ASA as of 31 December 2022:
6,290
Loans from Equinor:
 
None
Experience:
 
Møllerstad has been employed by Equinor since 1991 and works within petroleum technology
 
discipline in
Exploration & Production International. Møllerstad has been a member of the Corporate Assembly
 
in Equinor from 2013 - 2019
and was a board member of Tekna Private from 2012 - 2017 and she has had several trust offices in Tekna Equinor since 1993.
Education:
 
Chartered engineer from Norwegian University of Science and Technology (NTNU) and Project Management
Essential (PME) from Norwegian Business School BI/ Norwegian University of Science and
 
Technology (BI/NTNU).
Family relations:
No family relationships to other board members, members of the corporate executive committee
 
or the
corporate assembly.
Other matters:
In 2022, Møllerstad participated in eight ordinary board meetings, four extraordinary board meetings
 
and five
meetings of the audit committee. Møllerstad is a Norwegian citizen and resident in Norway.
The composition of the board of directors changed as follows in 2022: Michael D. Lewis was
 
elected to the board with effect from
1 July 2022; Jeroen van der Veer left the board as of 30 June 2022 and Anne Drinkwater replaced him as the deputy chair as of 1 July
2022; Haakon Bruun-Hanssen was elected with effect from 12 December 2022 replacing Bjørn Tore Godal who left the board as of 11
December 2022.
Members of Equinor's corporate executive committee as of 31 December 2022:
Anders Opedal
Born:
 
1968
Position:
 
President and chief executive officer (CEO) since 2 November 2020
External offices:
 
None
Numbers of shares in Equinor ASA as of 31 December
2022
 
46,996
Loans from Equinor:
 
None
Experience:
 
Opedal joined Equinor in 1997. From 2018 -2020 he held the position of Executive Vice President Technology,
Projects and Drilling. From August to October 2018, he was Executive Vice President for Development,
 
Production Brazil and
prior to this Senior Vice President for Development, Production International Brazil. He also held
 
the position as Equinor’s Chief
Operating Officer. In 2011
 
he took on the role as Senior Vice President in Technology, Projects and Drilling; where he was
responsible for Equinor’s NOK 300 billion project portfolio. From 2007 - 2010 he served
 
as Chief Procurement Officer. He has
held a range of technical, operational and leadership positions in the company and started
 
as a petroleum engineer in the
Statfjord operations. Prior to Equinor Opedal worked for Schlumberger and Baker Hughes.
Education:
 
MBA from Heriot-Watt University and master's degree in Engineering (sivilingeniør) from the Norwegian Institute
 
of
Technology (NTH) in Trondheim.
Family relations:
 
No family relations to other members of the corporate executive committee, members
 
of the board or the
corporate assembly.
Other matters:
 
Opedal is a Norwegian citizen and resident in Norway.
Torgrim Reitan
Born
: 1969
Position:
 
Executive Vice President and Chief Financial Officer since 6 October 2022
External offices:
 
None
Number of shares held in Equinor ASA as of 31 December 2022
: 11,473
Loans from Equinor
:
Experience:
Reitan joined Equinor in 1995. He comes from the position of Senior Vice President for Finance and
 
Control in
Equinor’s Renewables business area, which he held since 2020. From 2018 - 2020 he was Executive
 
Vice President for
Development and production international, and from 2015 - 2018 Reitan held the position as Executive
 
Vice President of
Development and Production USA. Prior to this he held the position as Executive Vice President
 
and Chief Financial Officer from
2010 - 2015. He has held several management positions in Equinor prior to this, including Senior
 
Vice President in trading and
operations in the Natural gas business area in 2009 - 2010, Senior Vice President in Performance
 
management and analysis
from 2007 - 2009, and from 2005 - 2007 he was Senior Vice President in Performance Management, Tax and M&A. From 1995 -
2004 Reitan held various positions in the Natural Gas business area and corporate
 
functions.
Education:
Master of science degree from the Norwegian School of Economics and Business
 
administration (NHH).
Family relations:
No family relations to other members of the Corporate Executive Committee,
 
members of the Board or the
Corporate Assembly.
Other matters:
Torgrim Reitan is a Norwegian citizen and resident in Norway.
Jannicke Nilsson
Born:
 
1965
Position:
 
Executive vice president safety, security & sustainability (SSU) since 1 June 2021
External offices
: Member of the board of Odfjell SE and Jotun A/S
Number of shares in Equinor ASA as of 31 December 2022:
 
59,380
Loans from Equinor:
 
None
Experience:
 
Nilsson joined Equinor in 1999. She comes from the position of Executive Vice President and COO,
 
which she held
from 1 December 2016. As COO, she established the Digital Centre of Excellence
 
in 2017 to drive Equinor digital transformation
to deliver tangible performance within its always safe, high value and low carbon values. In August
 
2013 she was appointed
Programme Leader for the Equinor Technical Efficiency Programme (STEP). She has held a number of central management
positions within Upstream Operations Norway, including Senior Vice President for Technical Excellence in Technology,
 
Projects
& Drilling, Senior Vice President for Operations North Sea, Vice President for Modifications and Project Portfolio Bergen
 
and
Platform Manager at Oseberg South.
Education:
 
MSc in cybernetics and process automation and a BSc in automation from the Rogaland Regional
 
College/University
of Stavanger.
Family relations
: No family relations to other members of the corporate executive committee, members
 
of the board or the
corporate assembly.
Other matters:
Nilsson is a Norwegian citizen and resident in Norway.
Kjetil Hove
Born:
 
1965
Position:
 
Executive vice president Exploration & Production Norway (EPN) since 1
 
January 2021
External offices:
 
Member of the board of The Norwegian Oil & Gas Association (Norsk Olje
 
& Gass)
Number of shares in Equinor ASA as of 31 December 2022:
 
20,149
 
 
Loans from Equinor:
 
None
Experience:
 
Hove joined Equinor in 1991. He has held several central management positions
 
in Equinor. He comes from the
position of Senior Vice President Field Life Extension, which he held since January 2020. Prior to this, Hove
 
was Senior Vice
President for Operations Technology in Development & Production Norway. From 2000 - 2012 he worked internationally,
including as Country Manager for Equinor in Brazil for 3.5 years. Hove started his career in
 
1991 in Norsk Hydro within petroleum
technology holding various positions within exploration, field development and operations in Norway.
Education:
 
Master’s degree in petroleum engineering from Norwegian University
 
of Science and Technology (NTNU).
Family relations:
 
No family relations to other members of the corporate executive committee, members
 
of the board or the
corporate assembly.
Other matters:
 
Hove is a Norwegian citizen and resident in Norway.
Alasdair Cook
Born:
1975
Position:
Executive Vice President, Exploration & Production International (EPI) since 1 January 2021
External offices:
 
Member of the Board of The Power of Nutrition
Number of shares in Equinor ASA as of 31 December 2022
: 3,738
 
Loans from Equinor:
 
None
Experience:
 
Cook joined Equinor in 2016. He comes from the position of Executive Vice President Global
 
Strategy & Business
Development (GSB), which he had since May 2018. He started as SVP in Development &
 
Production International (DPI)
overseeing operations in Angola, Argentina, Azerbaijan, Libya, Nigeria, Russia and Venezuela. He joined from bp, where he was
Chief of Staff to the CEO. From 2009 - 2014 Cook led the development of the Southern Gas Corridor from
 
Azerbaijan to Europe.
From 2005 - 2009 he led exploration and project developments in Vietnam and acted as President
 
for bp Vietnam. He worked in
field operations in the North Sea from 2002 - 2005, becoming Offshore Installation Manager on the Cleeton
 
platform. Cook joined
bp in 1996, initially working in commercial, project and exploration roles.
Education:
 
MA in Natural Sciences from St. John’s College, Cambridge University and International Executive
 
Programme at
INSEAD.
Family relations:
 
No family relations to other members of the Corporate Executive Committee,
 
members of the Board or the
Corporate Assembly.
Other matters:
 
Cook is a UK citizen and resident in the UK. Cook left the CEC as of 31 December
 
2022.
Geir Tungesvik
Born:
1961
Position:
Executive Vice President, Projects, Drilling and Procurement (PDP), since 1 May 2022
External offices:
 
None
Number of shares held in Equinor ASA as of 31 December 2022
: 17,624
Loans from Equinor ASA:
 
None
Experience:
 
Geir Tungesvik joined Equinor in 1985. He comes from the position as Senior Vice President Project Development.
Previously he has held central management positions in the company including the position as Senior
 
Vice President for Drilling
and Well, Vice President for exploration drilling, Vice President for Grane production field and Vice President for health, safety
and environment in Exploration.
Education:
 
Master of Science degree in petroleum from the University of Stavanger (UIS)
 
and Master module in strategic
management from the Norwegian Business School (BI).
Family relations:
 
No family relations to other members of the Corporate Executive Committee,
 
members of the Board or the
Corporate Assembly.
Other matters:
 
Tungesvik is a Norwegian citizen and resident in Norway.
Irene Rummelhoff
Born:
 
1967
Position:
 
Executive vice president Marketing, Midstream & Processing (MMP) since
 
17 August 2018
External offices:
 
Deputy chair of the board of Norsk Hydro ASA.
Number of shares in Equinor ASA as of 31 December 2022
: 28,152
Loans from Equinor:
 
None
Experience:
 
Rummelhoff joined Equinor in 1991. She has held a number of management positions within international business
development, exploration, and the downstream business in Equinor. Her most recent position, which she held from June 2015,
was as Executive Vice President New Energy Solutions (NES).
Education:
 
Master’s degree in Petroleum Geosciences from the Norwegian Institute
 
of Technology (NTH).
Family relations:
 
No family relations to other members of the corporate executive committee, members
 
of the board or the
corporate assembly.
Other matters:
 
Rummelhoff is a Norwegian citizen and resident in Norway.
Pål Eitrheim
Born:
 
1971
Position:
 
Executive vice president Renewables (REN) since 17 August 2018
External offices:
 
Member of the board of the Confederation of Norwegian Enterprise (NHO)
Number of shares in Equinor ASA as of 31 December 2022
: 19,644
Loans from Equinor:
 
None
Experience:
Eitrheim joined Equinor in 1998. He has held a range of leadership positions in Equinor
 
in Azerbaijan, Washington
DC, the CEO office, corporate strategy and Brazil. In 2017-2018 he was Chief Procurement Officer. Between 2014 - 2017 he led
Equinor’s upstream business in Brazil.
 
In 2013 Eitrheim led the Secretariat for the investigation into the terrorist attack on the In
Amenas gas processing facility in Algeria.
Education:
 
Master’s degree in Comparative Politics from the University of Bergen,
 
Norway and University College Dublin,
Ireland.
Family relations:
 
No family relations to other members of the corporate executive committee, the
 
board or the corporate
assembly.
Other matters:
 
Eitrheim is a Norwegian citizen and resident in Norway.
Hege Skryseth
Born:
1967
Position:
 
Executive vice president and chief technical officer since 1 September 2022
External offices:
 
Member of the Board of Tomra, Netcompany and AutoStore
Number of shares in Equinor ASA as of 31 December 2022
: 2,633
Loans from Equinor ASA:
 
None
Experience:
 
Skryseth joined Equinor on 1 September 2022. She comes from the position as Executive Vice President of
Kongsberg, and President of Kongsberg Digital, a position which she held since 2013. Prior
 
to Kongsberg, Skryseth held various
leadership positions in international tech companies such as Microsoft Norway and Geodata (ESRI).
Education:
 
Executive MBA from NHH and Bachelor from BI, college graduate from
 
NITH.
Family relations:
No family relations to other members of the Corporate Executive Committee,
 
members of the Board or the
Corporate Assembly.
Other matters:
 
Skryseth is a Norwegian citizen and resident in Norway.
Siv Helen Rygh Torstensen
Born:
 
1970
Position:
 
Executive vice president and General Counsel Legal & Compliance (LEG)
 
since 1 June 2021
External offices:
 
Member of the Council of Ethics, the Government Pension Fund Global
Number of shares in Equinor ASA as of 31 December 2022
: 15,832
Loans from Equinor ASA:
 
None
Experience:
Rygh Torstensen joined Equinor in 1998. She comes from the position of Senior Vice President and General
Counsel, which she held since 1 August 2019. Prior to that she held the position as Head
 
of CEO office from July 2016. From
2011 - 2016 she was Vice President Corporate in LEG. From 1998 - 2011 Rygh Torstensen
 
held various positions within LEG,
including as Corporate Compliance Office and Acting General Counsel. Before joining Equinor she
 
worked with the law firm
Cappelen & Krefting DA and as a lawyer for Stavanger municipal council.
Education:
 
Master of Law from the University of Bergen, Norway, and licensed as an Attorney at Law.
Family relations:
 
No family relations to other members of the corporate executive committee, members
 
of the board or the
corporate assembly.
Other matters:
 
Rygh Torstensen is a Norwegian citizen and resident in Norway.
Jannik Lindbæk
Born:
1965
Position:
Executive Vice President Communication since 1 March 2022
External offices:
 
None
Number of shares in Equinor ASA as of 31 December 2022
: 12,542
Loans from Equinor ASA:
 
None
Experience:
Lindbæk joined Equinor in 2010. He was appointed Senior Vice President Communication 1 January
 
2021. He was
Vice President Corporate Communications Political & Public Affairs Norway from 2019-2021. Prior to this he was Equinor’s
 
Vice
President for communication in Brussels, before that in the CFO Global Business Services,
 
and as Vice President Media
Relations from 2010-2015. Before joining Equinor, Lindbæk was SVP Corporate Communication in Aker Solutions, PR manager
in Microsoft and PR consultant in BWPR and GCI Monsen.
Education:
Master’s degree in Comparative Politics from the University of Bergen
 
and London School of Economics.
Family relations:
No family relations to other members of the Corporate Executive Committee,
 
members of the Board or the
Corporate Assembly.
Other matters:
 
Lindbæk is a Norwegian citizen and resident in Norway.
Aksel Stenerud
Born:
1963
Position:
Executive vice president, People & Organisation (PO) since 1 March 2022
External offices:
Member of the board of Flow Group Norge AS
Number of shares held in Equinor ASA as of 31 December 2022
: 9,372
Loans from Equinor ASA:
None
Experience:
Stenerud joined Equinor in 2008 and has held various leadership roles across the
 
company. His most recent
position, which he held from November 2021, was Vice President Employee Relations in Corporate PO. From
 
August 2018, he
was Vice President for PO in Exploration and Production International. He has also served as Vice President
 
for Exploration and
Production Norway from 2014-2018. Stenerud has had a long international career within HR and prior to
 
this he served as an
officer in the Norwegian Airforce.
Education:
Graduate from the Air Defense academy. Minor and Intermediate in phsycology with the Norwegian university of
science and technology in Trondheim.
Family relations:
No family relations to other members of the Corporate Executive Committee,
 
members of the Board or the
Corporate Assembly.
Other matters:
 
Stenerud is a Norwegian citizen and resident in Norway.
The following changes were made to the Corporate Executive Committee during 2022:
As of 1 March, Jannik Lindbæk became a member of the corporate executive committee as EVP
 
COM and at the same date
Aksel Stenerud replaced Ana Fonseca Nordang as EVP PO. Carrie Lockhart left the position
 
as EVP for TDI as of 21 March,
Elisabeth B. Kvalheim took over as acting EVP TDI and Hege Skryseth became EVP TDI
 
as of 1 September. Arne Sigve Nylund
retired and Geir Tungesvik became EVP PDP as of 1 May. Torgrim
 
Reitan replaced Ulrica Fearn as CFO as of 6 October. Alasdair
Cook left the company as of 31 December 2022 and Philippe F. Mathieu became EVP EPI from 1 January 2023.
The information set forth under the heading “Corporate Assembly” in Section
 
5.1 of Chapter 5 on pages 270 – 272 of the 2022
Annual Report is also incorporated herein by reference.
B.
 
Compensation
The information set forth under the following headings of the 2021 Remuneration Policy included
 
as an appendix to the 2022
Remuneration Report which is attached hereto as Exhibit 15.6 (the “2022 Remuneration Report”)
 
is incorporated herein by reference:
●
 
Remuneration to the board of directors;
 
●
 
Remuneration to the corporate assembly; and
●
 
Remuneration to the CEC.
The information set forth under the following headings of the 2022 Remuneration Report is incorporated
 
herein by reference:
●
 
Overall company performance in 2022;
 
●
 
Performance-based modifiers used in calculating variable pay;
●
 
Summary of targets and achievement of corporate KPIs and goals forming the basis for annual
 
variable pay;
 
●
 
Key developments in corporate executive remuneration in 2022;
●
 
Derogations and deviations from remuneration policy;
●
 
Right to reclaim (‘malus and clawback’);
●
 
Remuneration and share ownership of the board of directors and corporate assembly;
●
 
Remuneration of the CEC;
●
 
Shares awarded or due to the CEC for the reported financial year;
●
 
Total number and value of shares held by the CEC; and
●
 
Performance and AVP awarded to the CEC members in the reported financial year.
See also note 22 Pensions to the Consolidated financial statements.
C.
 
Board Practices
The information set forth under the following headings of the 2022 Annual Report is incorporated herein by reference:
●
 
Governing bodies in Section 1.8 of Chapter 1 on page 33;
●
 
Corporate Assembly, board of directors and management in Section 5.1 of Chapter 5 on pages 270 – 272; and
●
 
The board of directors’ committees in Section 5.1 of Chapter 5 on page 273.
See also “Item 6. Directors, Senior Management and Employees—A. Directors and Senior Management”
 
of this 2022 Form 20-F
for more information regarding the expiration date of the current term of office of the members of our
 
board of directors and the period
during which our directors have served in such capacity, and the composition of the board of directors’ committees.
D.
 
Employees
The information set forth under the following headings of the 2022 Annual Report is incorporated herein by reference:
●
 
Contextual introduction and Management approach in Section 2.1.4 of Chapter 2 on pages
 
64 – 65;
●
 
The information set forth under the heading ‘Employment’ in Section 2.1.4 of Chapter 2
 
on page 67;
●
 
The table entitled ‘Permanent employees in the Equinor group as of 31 December 2022’ in Section
 
2.1.4 of
Chapter 2 on page 67 – 68; and
●
 
The table entitled ‘Total workforce by region and employment type in the Equinor group in 2022 as of 31 December
2022’ in Section 2.1.4 of Chapter 2 on page 68.
E.
 
Share Ownership
The information set forth under the following headings of the 2022 Remuneration Report is incorporated herein by
 
reference:
●
 
Total number and value of shares held by the members of the board of directors;
●
 
Shares held by the members of the corporate assembly; and
●
 
Total number and value of shares held by the CEC.
F.
Disclosure of a registrant’s action to recover erroneously awarded compensation
Not applicable.
ITEM 7. MAJOR SHAREHOLDERS AND RELATED PARTY TRANSACTIONS
A.
 
Major shareholders
The information set forth under the heading “
Major Shareholders
” in Section 5.3 of Chapter 5 on pages 284 – 285 of the 2022
Annual Report is incorporated herein by reference.
B.
 
Related Party Transactions
As part of its general loan arrangement for Equinor employees, Equinor has granted loans
 
to Equinor-employed spouses of
certain members of the corporate executive committee. Permanent employees in certain specified
 
employee categories may take out
a car loan from Equinor in accordance with standardised provisions set by the company. The standard maximum car loan is limited to
the cost of the car, including registration fees, but not exceeding NOK 300,000. Employees outside the collective labour area are
entitled to a car loan up to NOK 475,000 (managers) or NOK 575,000 (vice presidents and senior vice
 
presidents). The car loan is
interest-free, but the tax value, "interest advantage", must be reported as salary. Permanent employees of Equinor ASA may also
apply for a consumer loan up to NOK 350,000. The interest rate on consumer loans corresponds
 
to the standard rate in effect at any
time for “reasonable loans” from employer as decided by the Norwegian Ministry of Finance, i.e.,
 
the lowest rate an employer may
offer without triggering taxation of the benefit for the employee.
The information set forth under the heading “
Equal treatment of shareholders and transactions with close associates
” in Section
5.1 of Chapter 5 on pages 267 – 268 of the 2022 Annual Report is also incorporated herein
 
by reference. See also note 27 Related
parties to the Consolidated Financial Statements.
C.
 
Interests of Experts and Counsel
Not applicable.
ITEM 8. FINANCIAL INFORMATION
A.
 
Consolidated Statements and Other Financial Information
See “Item 18. Financial Statements” of this 2022 Form 20-
F.
 
Dividend policy and dividends
The information set forth under the following headings of the 2022 Annual Report is incorporated
 
herein by reference:
●
 
Capital distribution in Section 1.6 of Chapter 1 on page 30;
●
 
Capital distribution in Section 2.2 of Chapter 2 on page 71; and
●
 
Equity and dividends in Section 5.1 of Chapter 5 on pages 266 – 267.
See also note 20 Shareholders’ equity and dividends to the Consolidated financial statements.
Legal or arbitration proceedings
Equinor is involved in a number of proceedings globally concerning matters arising in connection
 
with the conduct of its
business. No further update is provided on previously reported legal or arbitration proceedings.
 
Equinor does not believe such
proceedings will, individually or in the aggregate, have a significant effect on Equinor’s financial position, profitability, results of
operations or liquidity.
 
See also note 11 Income taxes and note 26 Other commitments, contingent liabilities and contingent assets to
the Consolidated Financial Statements.
B.
 
Significant Changes
None.
ITEM 9. THE OFFER AND LISTING
A.
 
Offer and Listing Details
Equinor's shares have been listed on the Oslo
 
Børs (ticker: EQNR) and the New York Stock Exchange in the form of American
Depositary Shares (ADS) (ticker: EQNR) since our
 
initial public offering on 18 June 2001. The ADSs
 
traded on the New York Stock Exchange
are evidenced by American Depositary Receipts
 
(ADR), and each ADS represents one ordinary
 
share.
B.
 
Plan of Distribution
Not applicable.
C.
 
Markets
See “Item 9.A
―The Offer and Listing―Offer and Listing Details” of
 
this 2022
 
Form 20-
F.
D.
 
Selling Shareholders
Not applicable.
E.
 
Dilution
Not applicable.
F.
Expenses of the Issue
Not applicable.
ITEM 10. ADDITIONAL INFORMATION
A.
 
Share Capital
Not applicable.
B.
 
Memorandum and Articles of Association
Equinor's current articles of association were adopted at the annual general meeting of shareholders on 11 May 2022. The
articles of association are included as exhibit 1 to this 2022 Form 20-
F.
Summary of Equinor’s articles of association:
Name of the company
The registered name is Equinor ASA. Equinor is a Norwegian public limited company.
Registered office
Equinor’s registered office is in Stavanger, Norway, registered with the Norwegian Register of Business Enterprises under
number 923 609 016.
Objective of the company
The objective of Equinor ASA is to develop, produce and market various forms of energy and derived products and
 
services, as
well as other business. The activities may also be carried out through participation in or cooperation
 
with other companies.
Share capital
Equinor’s share capital is NOK 7,938,675,397.50 divided into 3,175,470,159 shares.
Nominal value of shares
The nominal value of each ordinary share is NOK 2.50.
Board of directors
Equinor’s articles of association provide that the board of directors shall consist of 9 - 11 directors. The board, including the chair
and the deputy chair, shall be elected by the corporate assembly for a period of up to two years.
Corporate assembly
Equinor has a corporate assembly comprising 18 members who are normally elected for a term
 
of two years. The general
meeting elects 12 members with four deputy members, and six members with deputy members
 
are elected by and among the
employees.
General meetings of shareholders
Equinor’s annual general meeting is held no later than 30 June each year. The annual general meeting shall address and
 
decide
adoption of the annual report and accounts, including the distribution of any dividend and any
 
other matters required by law or the
articles of association.
Documents related to the general meetings do not need to be sent to all shareholders
 
if they are accessible on Equinor’s website.
A shareholder may request that such documents be sent to him/her.
Shareholders may vote in writing, including through electronic communication, during a specified
 
period before the general
meeting. Equinor's board of directors adopted guidelines for advance voting in March 2012,
 
and these guidelines are described in the
notices of the annual general meetings.
Marketing of petroleum on behalf of the Norwegian State
Equinor’s articles of association provide that Equinor is responsible for marketing and selling
 
petroleum produced under the
State’s direct financial interest’s (SDFI) shares in production licences on the Norwegian continental shelf as well as petroleum
received by the Norwegian State paid as royalty together with its own production. Equinor’s
 
general meeting adopted an instruction in
respect of such marketing on 25 May 2001, as most recently amended by authorisation of the
 
annual general meeting on 15 May
2018.
Nomination committee
The tasks of the nomination committee are to present a recommendation to:
●
The general meeting regarding the election of shareholder-elected members and
 
deputy members of the corporate assembly.
●
The general meeting regarding the election of members of the nomination committee.
●
The general meeting
 
for the remuneration of members of the corporate assembly and the nomination committee.
 
●
The corporate assembly regarding the election of shareholder-elected members to the board of
 
directors.
●
The corporate assembly for the remuneration for members of the board of directors.
●
The corporate assembly for election of the chair and the deputy chair of the corporate assembly.
The general meeting may adopt instructions for the nomination committee.
Exhibit 2.1 to this 2022 Form 20-F is also incorporated herein by reference.
C.
 
Material Contracts
The information set forth under the heading “Manufacturing”
 
in Section 3.3 of Chapter 3 on page
 
145 of the 2022 Annual Report is
incorporated herein by reference. See also note 27
 
Related parties to the Consolidated financial
 
statements.
D.
 
Exchange controls
Under Norwegian foreign exchange controls currently in effect, transfers of capital to and from Norway are not
 
subject to prior
government approval. An exception applies to the physical transfer of payments in
 
currency exceeding certain thresholds, which
must be declared to the Norwegian custom authorities. This means that non-Norwegian resident
 
shareholders may receive
dividend payments without Norwegian exchange control consent as long as the payment is made
 
through a licensed bank or other
licensed payment institution.
There are no restrictions affecting the rights of non-Norwegian residents or foreign owners to hold or vote for
 
our shares.
E.
 
Taxation
Norwegian tax consequences
This section describes material Norwegian tax consequences for shareholders in connection with
 
the acquisition, ownership
and disposal of shares and American Depositary Shares (“ADS”) in Equinor. The term “shareholders” refers to both holders of
shares and holders of ADSs, unless otherwise explicitly stated.
The outline does not provide a complete description of all Norwegian tax regulations that might be relevant
 
(i.e. for investors
to whom special regulations may apply, including shareholders that carry on business activities in Norway, and whose shares or
ADSs are effectively connected with such business activities), and is based on current law and practice. Shareholders
 
should
consult their professional tax advisers for advice about individual tax consequences.
Taxation of dividends received by Norwegian shareholders
Corporate shareholders (i.e., limited liability companies and similar entities) residing in Norway for tax
 
purposes are generally
subject to tax in Norway on dividends received from Norwegian companies. The basis for
 
taxation is 3% of the dividends received,
which is subject to the standard income tax rate of 22% (25% for financial institutions), implying
 
that such dividends are effectively
taxed at a rate of 0.66% (0.75% for financial institutions).
Individual shareholders residing in Norway for tax purposes are subject to tax for dividend income
 
exceeding a basic tax-free
allowance. For dividend distributions resolved from 1 January 2022 to 5 October 2022, the
 
dividend income exceeding the basic
tax-free allowance is grossed up with a factor of 1.6 before being included in the ordinary taxable
 
income, resulting in an effective
tax rate of 35.2% (22% x 1.6). For dividend distributions resolved on 6. October 2022 or later, dividend income exceeding the
basic tax-free allowance is grossed up with a factor of 1.72 before being included in the ordinary
 
taxable income, resulting in an
effective tax rate of 37.84% (22% x 1.72). For the income year 2023, the dividend income exceeding the basic
 
tax-free allowance
is also grossed up with a factor of 1.72, resulting in an effective tax rate of 37.84% (22%
 
x 1.72).
The tax-free allowance is computed for each individual share or ADS and corresponds as a rule
 
to the cost price of that share
or ADS multiplied by an annual risk-free interest rate. Any part of the calculated allowance for one
 
year that exceeds the dividend
distributed for the share or ADS (“unused allowance”) may be carried forward and set off against future dividends
 
received on (or
gains upon the realisation of, see below) the same share or ADS. Any unused allowance
 
will also be added to the basis for
computation of the allowance for the same share or ADS the following year.
Individual shareholders residing in Norway for tax purposes may hold the shares (but not ADS) in Equinor
 
through a stock
savings account. Dividend on shares owned through the stock savings account is only taxable when
 
the dividend is withdrawn
from the account.
Taxation of dividends received by foreign shareholders
Non-resident shareholders are as a starting point subject to Norwegian withholding tax at a
 
rate of 25% on dividends from
Norwegian companies. The distributing company is responsible for deducting the withholding tax
 
upon distribution to non-resident
shareholders.
Corporate shareholders that carry on business activities in Norway, and whose shares or ADSs are effectively connected with
such activities are not subject to withholding tax. For such shareholders, 3% of the received dividends
 
are subject to the standard
income tax of 22% (25% for financial institutions).
Certain other important exceptions and modifications are outlined below.
The withholding tax does not apply to corporate shareholders in the EEA that are comparable
 
to Norwegian limited liability
companies or certain other types of Norwegian entities, and are further able to demonstrate that
 
they are genuinely established
and carry on genuine economic business activity within the EEA.
The withholding rate of 25% is often reduced in tax treaties between Norway and other countries. The reduced
 
withholding
tax rate will generally only apply to dividends paid on shares held by shareholders who
 
are able to properly demonstrate that they
are the beneficial owner and entitled to the benefits of the tax treaty.
Individual shareholders residing for tax purposes in the EEA may apply to the Norwegian tax authorities
 
for a refund if the tax
withheld by the distributing company exceeds the tax that would have been levied
 
on individual shareholders resident in Norway.
Individual shareholders residing for tax purposes in the EEA may hold the listed shares (but not ADS)
 
in Equinor through a
Norwegian stock savings account. Dividend on shares owned through the stock savings account
 
will only be subject to withholding
tax when withdrawn from the account.
Procedure for claiming a reduced withholding tax rate on dividends
A foreign shareholder that is entitled to an exemption from or reduction of withholding tax on dividends,
 
may request that the
exemption or reduction is applied at source by the distributor. Such request must be accompanied by satisfactory documentation
which supports that the foreign shareholder is entitled to a reduced withholding tax
 
rate. Specific documentation requirements
apply.
For holders of shares and ADSs deposited with JPMorgan Chase Bank N.A. (JPMorgan),
 
documentation establishing that the
holder is eligible for the benefits under a tax treaty with Norway, may be provided to JPMorgan. JPMorgan has been granted
permission by the Norwegian tax authorities to receive dividends from us for redistribution
 
to a beneficial owner of shares and
ADSs at the applicable treaty withholding rate.
The statutory 25% withholding tax rate will be levied on dividends paid to shareholders (either directly
 
or through a
depositary) who have not provided the relevant documentation to the relevant party that they
 
are eligible for a reduced rate. The
beneficial owners will in this case have to apply to Skatteetaten (The Norwegian Tax Administration) for a refund of the excess
amount of tax withheld. Please refer to the tax authorities’ web page for more information and
 
the requirements of such
application: www.skatteetaten.no/en/person.
Taxation on realisation of shares and ADSs
Corporate shareholders resident in Norway for tax purposes are not subject to tax in Norway
 
on gains derived from the sale,
redemption or other disposal of shares or ADSs in Norwegian companies. Capital losses are not
 
deductible.
Individual shareholders residing in Norway for tax purposes are subject to tax in Norway on the sale,
 
redemption or other
disposal of shares or ADSs. Gains or losses in connection with such realisation are included in
 
the individual's ordinary taxable
income in the year of disposal, which is subject to the standard income tax rate of 22%. For shares realized
 
in 2022, and prior to 6
October, taxable gain or deductible loss is grossed up with a factor of 1.6 before included in the ordinary taxable income, resulting
in an effective tax rate of 35.2% (22% x 1.6). For shares realized on 6 October 2022 onwards, taxable gain
 
or deductible loss is
grossed up with a factor of 1.72 before included in the ordinary taxable income, resulting in an
 
effective tax rate of 37.84% (22% x
1.72). For shares realized in 2023, the taxable gain or deductible loss is also grossed up with
 
a factor of 1.72, resulting in an
effective tax rate of 37.84% (22% x 1.72).
The taxable gain or deductible loss (before grossing up) is calculated as the sales price adjusted
 
for transaction expenses minus
the taxable basis. A shareholder's tax basis is normally equal to the acquisition cost of the shares
 
or ADSs. Any unused allowance
pertaining to a share may be deducted from a taxable gain on the same share or ADS but may
 
not lead to or increase a deductible
loss. Furthermore, any unused allowance may not be set off against gains from the realisation of the other shares
 
or ADSs.
If a shareholder disposes of shares or ADSs acquired at different times, the shares or ADSs that were first acquired
 
will be
deemed to be first sold (the “FIFO” principle) when calculating gain or loss for tax
 
purposes.
Individual shareholders residing in Norway for tax purposes may hold the shares (but not ADS) in
 
Equinor through a stock
savings account. Gain on shares owned through the stock savings account will only be taxable
 
when withdrawn from the account
whereas loss on shares will be deductible when the account is terminated.
A corporate shareholder or an individual shareholder who ceases to be tax resident in Norway
 
due to Norwegian law or tax
treaty provisions may, in certain circumstances, become subject to Norwegian exit taxation on unrealised capital gains related to
shares or ADSs.
Shareholders not residing in Norway are generally not subject to tax in Norway on capital gains, and
 
losses are not deductible on
the sale, redemption or other disposal of shares or ADSs in Norwegian companies,
 
unless the shareholder carries on business
activities in Norway and such shares or ADSs are or have been effectively connected with such activities.
Wealth tax
The shares or ADSs are included in the basis for the computation of wealth tax imposed
 
on individuals residing in Norway for
tax purposes. Norwegian limited liability companies and certain similar entities are not subject to
 
wealth tax.
For the income year 2022, the net wealth tax is 0.95% for net worth above a minimum
 
threshold of NOK 1,700,000, and 1.1%
for net worth above a minimum threshold of NOK 20,000,000. The assessment value of listed shares
 
(including ADSs) for the
2022 wealth tax is 75% of the listed value of such shares or ADSs on 1 January 2023.
For the income year 2023, the net wealth tax is 1.0% for net worth above a minimum threshold
 
of NOK 1,700,000, and 1.1%
for net worth above a minimum threshold of NOK 20,000,000. The assessment value of listed
 
shares (including ADSs) for the
2023 wealth tax is 80% of the listed value of such shares or ADSs on 1 January 2024.
Non-resident shareholders are not subject to wealth tax in Norway for shares and ADSs in
 
Norwegian limited liability
companies unless the shareholder is an individual and the shareholding is effectively connected with the individual's
 
business
activities in Norway.
Inheritance tax and gift tax
No inheritance or gift tax is imposed in Norway.
Transfer tax
No transfer tax is imposed in Norway in connection with the sale or purchase of shares or
 
ADSs.
United States tax matters
This section describes the material United States federal income tax consequences for US holders (as
 
defined below) of the
ownership and disposition of shares or ADSs. It only applies to you if you hold your shares or
 
ADSs as capital assets for United
States federal income tax purposes. This discussion addresses only United States federal income taxation
 
and does not discuss
all of the tax consequences that may be relevant to you in light of your individual circumstances,
 
including foreign, state or local
tax consequences, estate and gift tax consequences, and tax consequences arising
 
under the Medicare contribution tax on net
investment income or the alternative minimum tax. This section does not apply to you
 
if you are a member of a special class of
holders subject to special rules, including dealers in securities, traders in securities that elect to use
 
a mark-tomarket method of
accounting for securities holdings, tax-exempt organisations, insurance companies, partnerships or entities
 
or arrangements that
are treated as partnerships for United States federal income tax purposes, persons that actually
 
or constructively own 10% of the
combined voting power of voting stock of Equinor or of the total value of stock of Equinor, persons that hold shares or ADSs as
part of a straddle or a hedging or conversion transaction, persons that purchase or sell shares or ADSs
 
as a part of a wash sale
for tax purposes, or persons whose functional currency is not USD.
This section is based on the Internal Revenue Code of 1986, as amended, its legislative history, existing and proposed
regulations, published rulings and court decisions, all as currently in effect, and the Convention between the United States
 
of
America and the Kingdom of Norway for the Avoidance of Double Taxation and the Prevention of Fiscal Evasion with Respect to
Taxes on Income and Property (the “Treaty”). These laws are subject to change, possibly on a retroactive basis. In addition, this
section is based in part upon the representations of the depositary and the assumption that
 
each obligation in the deposit
agreement and any related agreement will be performed in accordance with its terms. For United
 
States federal income tax
purposes, if you hold ADRs evidencing ADSs, you will generally be treated as the owner
 
of the ordinary shares represented by
those ADRs. Exchanges of shares for ADRs and ADRs for shares will not generally
 
be subject to United States federal income
tax.
A “US holder” is a beneficial owner of shares or ADSs that is, for United States federal
 
income tax purposes: (i) a citizen or
resident of the United States; (ii) a United States domestic corporation; (iii) an estate whose
 
income is subject to United States
federal income tax regardless of its source; or (iv) a trust if a United States court can
 
exercise primary supervision over the trust's
administration and one or more United States persons are authorised to control all substantial decisions
 
of the trust.
You should consult your own tax adviser regarding the United States federal, state and local and Norwegian and other tax
consequences of owning and disposing of shares and ADSs in your particular circumstances.
The tax treatment of the shares or ADSs will depend in part on whether or not we are classified
 
as a passive foreign
investment company, or PFIC, for United States federal income tax purposes. Except as discussed below, under “—PFIC rules”,
this discussion assumes that we are not classified as a PFIC for United States federal income
 
tax purposes.
Taxation of distributions
Under the United States federal income tax laws, the gross amount of any distribution (including
 
any Norwegian tax withheld
from the distribution payment) paid by Equinor out of its current or accumulated earnings and profits
 
(as determined for United
States federal income tax purposes), other than certain pro-rata distributions of its shares, will be treated
 
as a dividend that is
taxable for you when you, in the case of shares, or the depositary, in the case of ADSs, receive the dividend, actually or
constructively. If you are a non-corporate US holder, dividends that constitute qualified dividend income will be eligible to be taxed
at the preferential rates applicable to longterm capital gains as long as, in the year that
 
you receive the dividend, the shares or
ADSs are readily tradable on an established securities market in the United States or
 
Equinor is eligible for benefits under the
Treaty. We believe that Equinor is currently eligible for the benefits of the Treaty and we therefore expect that dividends on the
ordinary shares or ADSs will be qualified dividend income. To qualify for the preferential rates, you must hold the shares or ADSs
for more than 60 days during the 121-day period beginning 60 days before the ex-dividend date
 
and meet certain other
requirements. The dividend will not be eligible for the dividends-received deduction generally
 
allowed to United States
corporations in respect of dividends received from other United States corporations.
The amount of the dividend distribution that you must include in your income will be the
 
value in USD of the payments made
in NOK determined at the spot NOK/USD rate on the date the dividend is distributed, regardless of whether or
 
not the payment is
in fact converted into USD. Distributions in excess of current and accumulated earnings and profits,
 
as determined for United
States federal income tax purposes, will be treated as a non-taxable return of capital to the
 
extent of your tax basis in the shares
or ADSs and, to the extent in excess of your tax basis, will be treated as capital gain. However, Equinor does not expect to
calculate earnings and profits in accordance with United States federal income tax principles. Accordingly, you should expect to
generally treat distributions we make as dividends.
Subject to certain limitations, the 15% Norwegian tax withheld in accordance with the Treaty and paid to Norway will be
creditable or deductible against your United States federal income tax liability, unless a reduction or refund of the tax withheld is
available to you under Norwegian law. However, under recently finalized Treasury regulations, it is possible that taxes may not be
creditable unless you are eligible for and elect to apply the benefits of the Treaty. Special rules apply in determining the foreign tax
credit limitation with respect to dividends that are subject to the preferential tax rates. Dividends
 
will generally be income from
sources outside the United States and will generally be “passive” income for purposes
 
of computing the foreign tax credit
allowable to you. Any gain or loss resulting from currency exchange rate fluctuations during the
 
period from the date you include
the dividend payment in income until the date you convert the payment into USD will generally
 
be treated as US-source ordinary
income or loss and will not be eligible for the special tax rate.
Taxation of capital gains
If you sell or otherwise dispose of your shares or ADSs, you will generally recognise a capital gain or loss
 
for United States
federal income tax purposes equal to the difference between the value in USD of the
 
amount that you realise and your tax basis,
determined in USD, in your shares or ADSs. Capital gain of a non-corporate US
 
holder is generally taxed at preferential rates if
the property is held for more than one year. The gain or loss will generally be income or loss from sources within the United States
for foreign tax credit limitation purposes. If you receive any foreign currency on the sale
 
of shares or ADSs, you may recognise
ordinary income or loss from sources within the United States as a result of currency fluctuations
 
between the date of the sale of
the shares or ADSs and the date the sales proceeds are converted into USD. You should consult your own tax adviser regarding
how to account for payments made or received in a currency other than USD.
PFIC rules
We believe that the shares and ADSs should not currently be treated as stock of a PFIC for United
 
States federal income tax
purposes and we do not expect to become a PFIC in the foreseeable future. However, this conclusion is a factual determination
that is made annually and thus may be subject to change. It is therefore possible that we could
 
become a PFIC in a future taxable
year. If we were to be treated as a PFIC, a gain realised on the sale or other disposition of the shares or ADSs would
 
in general
not be treated as a capital gain. Instead, unless you elect to be taxed annually on a
 
mark-to-market basis with respect to the
shares or ADSs, you would generally be treated as if you had realised such gain
 
and certain “excess distributions” ratably over
your holding period for the shares or ADSs. Amounts allocated to the year in which the gain
 
is realised or the “excess distribution”
is received or to a taxable year before we were classified as a PFIC would be subject to tax at
 
ordinary income tax rates, and
amounts allocated to all other years would be taxed at the highest tax rate in effect for each
 
such year to which the gain or
distribution was allocated, together with an interest charge in respect of the tax
 
attributable to each such year. With certain
exceptions, your shares or ADSs will be treated as stock in a PFIC if we were a PFIC
 
at any time during the period you held the
shares or ADSs. Dividends that you receive from us will not be eligible for the preferential
 
tax rates if we are treated as a PFIC
with respect to you, either in the taxable year of the distribution or the preceding taxable year, but will instead be taxable at rates
applicable to ordinary income.
Foreign Account Tax Compliance Withholding
A 30% withholding tax will be imposed on certain payments to certain non-US financial institutions
 
that fail to comply with
information reporting requirements or certification requirements in respect of their direct and indirect United
 
States shareholders
and/or United States accountholders. To avoid becoming subject to the 30% withholding tax on payments to them, we and other
non-US financial institutions may be required to report information to the IRS regarding
 
the holders of shares or ADSs and to
withhold on a portion of payments under the shares or ADSs to certain holders that fail to
 
comply with the relevant information
reporting requirements (or hold shares or ADSs directly or indirectly through certain non-compliant
 
intermediaries). However,
under proposed Treasury regulations, such withholding will not apply to payments made before the date that is two years after the
date on which final regulations defining the term “foreign passthru payment” are enacted. The
 
rules for the implementation of
these requirements have not yet been fully finalised, so it is impossible to determine at this time
 
what impact, if any, these
requirements will have on holders of the shares and ADSs.
F.
Dividends and Paying Agents
Not applicable.
 
 
 
 
 
G.
 
Statement by Experts
Not applicable.
H.
 
Documents on Display
Our filings with the SEC are available to the public through the SEC’s website at http://www.sec.gov. We also make available on
our website, free of charge, our annual reports on Form 20-F, as well as certain other SEC filings, as soon as reasonably practicable
after they are electronically filed with or furnished to the SEC. The information on our website
 
is not incorporated by reference in this
document.
Documents related to us that are available to the public (this 2022 Form 20-F, the 2022 Annual Report, our Articles of
Association, our Code of Conduct, financial statements and our historical financial information for
 
each of the three financial years
preceding the publication of this 2022 Form 20-F) can be consulted on our website and at: Equinor ASA,
 
Forusbeen 50, 4035
Stavanger, Norway.
 
Unless stated otherwise, none of these documents form a part of this 2022
 
Form 20-
F.
I.
 
Subsidiary Information
Not applicable.
J.
 
Annual Report to Security Holders.
Not applicable.
ITEM 11. QUANTITATIVE
 
AND QUALITATIVE
 
DISCLOSURES ABOUT MARKET RISK
See notes 4 Financial risk and capital management and 28 Financial instruments and fair value
 
measurement to the
Consolidated Financial Statements.
ITEM 12. DESCRIPTION OF SECURITIES OTHER THAN EQUITY SECURITIES
A.
 
Debt Securities
Not applicable.
B.
 
Warrants and Rights
Not applicable.
C.
 
Other Securities
Not applicable.
D.
 
American Depositary Shares
Exhibit 2.1 to this 2022 Form 20-F is incorporated herein by reference.
Name of depositary and address of its principal executive office.
JPMorgan Chase Bank N.A. (JPMorgan), serves as the depositary for Equinor’s
 
ADR programme having replaced the Deutsche
Bank Trust Company Americas (Deutsche Bank) pursuant to the Further Amended and Restated Deposit Agreement dated
 
4
February 2019.
Fees and charges payable by a holder of ADSs
JPMorgan collects its fees for the delivery and surrender of ADSs directly from investors depositing shares
 
or surrendering ADSs
for the purpose of withdrawal, or from intermediaries acting for them. The depositary collects other fees from
 
investors by billing ADR
holders, by deducting such fees and charges from the amounts distributed or by deducting such
 
fees from cash dividends or other
cash distributions. The depositary may refuse to provide fee-attracting services until its fees
 
for those services are paid.
The charges of the depositary payable by investors are as follows:
ADR holders, persons depositing or withdrawing shares,
 
and/or persons whom ADSs are
issued, must pay:
For:
USD 5.00 (or less) per 100 ADSs (or portion of 100 ADSs)
Issuance of ADSs, including issuances resulting from a
deposit of shares, a distribution of shares or rights or other
property, and issuances pursuant
 
to stock dividends, stock
splits, mergers, exchanges of securities or any other
transactions or events affecting the ADSs or the
 
deposited
securities.
 
 
 
 
 
 
 
 
Cancellation of ADSs for the purpose of withdrawal
 
of
deposited securities, including if the deposit agreement
terminates, or a cancellation or reduction of ADSs for any
other reason
USD 0.05 (or less) per ADS
Any cash distribution made or elective cash/stock dividend
offered pursuant to the Deposit Agreement
USD 0.05 (or less) per ADS, per calendar year (or portion
 
thereof)
For the operation and maintenance costs in administering
the ADR programme
A fee equivalent to the fee that would be payable if securities
 
distributed to you had been shares
and the shares had been deposited for issuance of ADSs
Distribution to registered ADR holders of (i) securities
distributed by the company to holders of deposited
securities or (ii) cash proceeds from the sale of such
securities
Registration or transfer fees
Transfer and registration of shares on our share
 
register to
or from the name of the Depositary or its agent when you
deposit or withdraw shares
Expenses of the Depositary
SWIFT, cable, telex,
 
facsimile transmission and delivery
charges (as provided in the deposit agreement).
Fees, expenses and other charges of JPMorgan or its
agent (which may be a division, branch or affiliate) for
converting foreign currency to USD, which shall be
deducted out of such foreign currency.
Taxes and other
 
governmental charges the Depositary or the custodian
 
have to pay, for example,
stock transfer taxes, stamp duty or withholding taxes
As necessary
Any fees, charges and expenses incurred by the Depositary
 
or its agents for the servicing of the
deposited securities, the sale of securities, the delivery of
 
deposited securities or in connection with
the depositary's or its custodian's compliance with applicable
 
law, rule or regulation, including
without limitation expenses incurred on behalf of ADR holders
 
in connection with compliance with
foreign exchange control regulations or any law or
 
regulation relating to foreign investment
As necessary
Direct and indirect payments by the depositary
For the year ended 31 December 2022, J.P. Morgan reimbursed USD 2,000,000 to the company. Other reasonable costs
associated with the administration of the ADR programme are borne by the company. For the year ended 31 December 2022, such
costs, associated with the administration of the ADR programme, paid by the company, added up to USD 229,704. Under certain
circumstances, including the removal of J.P. Morgan as depositary,
 
the company is required to repay to J.P. Morgan certain amounts
paid to the company in prior periods.
ITEM 13. DEFAULTS, DIVIDEND ARREARAGES AND DELINQUENCIES
Not applicable.
ITEM 14. MATERIAL MODIFICATIONS TO
 
THE RIGHTS OF SECURITY HOLDERS AND USE OF PROCEEDS
Not applicable.
ITEM 15. CONTROLS AND PROCEDURES
Disclosure Controls and Procedures
The management of Equinor, with the participation of our chief executive officer and chief financial officer, has evaluated the
effectiveness of the design and operation of our disclosure controls and procedures pursuant to Exchange Act Rule
 
13a-15(b) as of
31 December 2022. Based on that evaluation, the chief executive officer and chief financial officer have concluded that
 
these
disclosure controls and procedures are effective at a reasonable level of assurance.
In designing and evaluating our disclosure controls and procedures, our management, with the
 
participation of the chief executive
officer and chief financial officer, recognised that any controls and procedures, no matter how well designed and operated, can only
provide reasonable assurance that the desired control objectives will be achieved, and
 
that the management must necessarily
exercise judgment when evaluating possible controls and procedures. Because of the limitations inherent
 
in all control systems, no
evaluation of controls can provide absolute assurance that all control issues and any instances of fraud
 
in the company have been
detected
Management’s Annual Report on Internal Control Over Financial Reporting
The management of Equinor is responsible for establishing and maintaining adequate internal control
 
over financial reporting.
Our internal control over financial reporting is a process designed, under the supervision of the chief executive
 
officer and chief
financial officer, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of Equinor’s
financial statements for external reporting purposes in accordance with International Financial Reporting
 
Standards (IFRS) as adopted
by the European Union (EU). The accounting policies applied by the group also comply with
 
IFRS as issued by the International
Accounting Standards Board (IASB).
The management of Equinor has assessed the effectiveness of internal control over financial reporting based on the
 
Internal
Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of
 
the Treadway Commission (COSO).
Based on this assessment, management has concluded that Equinor’s internal
 
control over financial reporting as of 31 December
2022 was effective.
 
Equinor’s internal control over financial reporting includes policies and procedures
 
that pertain to the maintenance of records that,
in reasonable detail, accurately and fairly reflect transactions and dispositions of assets, provide reasonable
 
assurance that
transactions are recorded in the manner necessary to permit the preparation of financial statements in
 
accordance with IFRS, and that
receipts and expenditures are only carried out in accordance with the authorisation of the management
 
and directors of Equinor; and
provide reasonable assurance regarding the prevention or timely detection of any unauthorised
 
acquisition, use or disposition of
Equinor’s assets that could have a material effect on our financial statements.
 
Because of its inherent limitations, internal control over financial reporting may not prevent or
 
detect all misstatements. Moreover,
projections of any evaluation of the effectiveness of internal control to future periods are subject to a risk that
 
controls may become
inadequate because of changes in conditions and that the degree of compliance with policies
 
or procedures may deteriorate.
 
Attestation Report of the Registered Public Accounting Firm
The effectiveness of internal control over financial reporting as of 31 December 2022 has been audited by Ernst & Young AS, an
independent registered accounting firm that also audits Equinor’s Consolidated Financial
 
Statements. Their audit report on the internal
control over financial reporting is included in the Consolidated Financial Statements.
Changes in Internal Control Over Financial Reporting
There were no significant changes in our internal control over financial reporting during the
 
year ended 31 December 2022 that
have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
ITEM 16. [RESERVED]
ITEM 16A. AUDIT COMMITTEE FINANCIAL EXPERT
Our board of directors has determined that both Anne Drinkwater and Rebekka Glasser Herlofsen qualify
 
as an “audit committee
financial expert” as defined in Item 16A of Form 20-F under the Exchange Act and each of them
 
is an independent director under Rule
10A-3 under the Exchange Act.
ITEM 16B. CODE OF ETHICS
We have adopted a Code of Conduct, which is approved by our board of directors, and applies to our board
 
members, all of our
employees (including our principal executive, principal financial and principal accounting officers) and hired personnel. Our Code
 
of
Conduct is filed as Exhibit 11 to this 2022 Form 20-
F.
In 2022, our board of directors approved certain amendments to our Code of Conduct, including:
-
 
Updates clarifying that “other follow-up of personnel” may be relevant in case of breach of the Code
 
of Conduct, such as
behavior goals or training; and
-
 
Updates clarifying that reporting commitments also cover non-financial reporting
 
In 2022, we did not grant any waiver, including any implicit waiver, from any provision of the Code of Conduct to our principal
executive officer, principal financial officer, principal accounting officer or controller,
 
or persons performing similar functions.
 
ITEM 16C. PRINCIPAL ACCOUNTANT FEES AND SERVICES
The information set forth under the heading “
External auditor
” in Section 5.1 of Chapter 5 on pages 275 – 276 of the 2022 Annual
Report is incorporated herein by reference. See also note 9 Auditor’s remuneration
 
and Research and development expenditures to
the Consolidated Financial Statements.
ITEM 16D. EXEMPTIONS FROM THE LISTING STANDARDS FOR AUDIT COMMITTEES
See “Item 16G. Corporate Governance―Board committees” of this 2022 Form 20-
F.
 
ITEM 16E. PURCHASES OF EQUITY SECURITIES BY THE ISSUER AND
 
AFFILIATED PURCHASERS
The information set forth under the headings “
Equinor’s share savings plan
”, “
Share buy-back
” and “
Summary of shares
repurchased
”
in Section 5.3 of Chapter 5 on pages 283 – 284 of the 2022 Annual Report is
 
also incorporated herein by reference.
ITEM 16F. CHANGE IN REGISTRANT’S CERTIFYING ACCOUNTANT
Not applicable.
ITEM 16G. CORPORATE GOVERNANCE
Equinor’s primary listing is on the Oslo Børs, and its ADRs are listed
 
on the NYSE. In addition, Equinor is a foreign private issuer
subject to the reporting requirements of the SEC. ADRs representing the company’s ordinary shares
 
are listed on the NYSE. While
Equinor’s corporate governance practices follow the requirements of Norwegian law, Equinor is also subject to the NYSE’s listing
rules. As a foreign private issuer, Equinor is exempt from most of the NYSE corporate governance standards that domestic US
companies must comply with. However, Equinor is required to disclose any significant ways in which its corporate governance
practices differ from those applicable to domestic US companies under the NYSE rules. A statement of differences is
 
set out below:
Corporate governance guidelines
The NYSE rules require domestic US companies to adopt and disclose corporate governance guidelines.
 
Equinor’s corporate
governance principles are developed by the management and the board of directors, in accordance with the
 
Norwegian Code of
Practice for Corporate Governance and applicable law. Oversight of the board of directors and management is exercised by the
corporate assembly.
Director independence
The NYSE rules require domestic US companies to have a majority of “independent directors”.
 
The NYSE definition of an
“independent director” sets out five specific tests of independence and requires an affirmative determination by the
 
board of directors
that the director has no material relationship with the company.
Pursuant to Norwegian company law, Equinor’s board of directors consists of members elected by shareholders and employees.
Equinor’s board of directors has determined that, in its judgment, all shareholder-elected
 
directors are independent. In making its
determinations of independence, the board focuses, among other things, on there not being
 
any conflicts of interest between
shareholders, the board of directors and the company’s management. It does not strictly make its determination
 
based on the NYSE’s
five specific tests but takes into consideration all relevant circumstances which may in the
 
board’s view affect the directors’
independence. The directors elected from among Equinor’s employees would not be considered
 
independent under the NYSE rules
as they are employees of Equinor. None of these employee representatives are executive officers of the company. For further
information about the board of directors, see “Item 6. Directors, Senior Management and Employees—A.
 
Directors and Senior
Management” of this 2022 Form 20-
F.
Board committees
Pursuant to Norwegian company law, managing the company is the responsibility of the board of directors. Equinor has an audit
committee, a safety, sustainability and ethics committee and a compensation and executive development committee. The audit
committee and the compensation and executive development committee operate pursuant to instructions
 
that are broadly comparable
to the applicable committee charters required by the NYSE rules. They report on a regular basis to, and are
 
subject to, oversight by
the board of directors.
Equinor complies with the NYSE rule regarding the obligation to have an audit committee that meets
 
the requirements of Rule
10A-3 of the US Securities Exchange Act of 1934. The members of Equinor’s
 
audit committee include an employee-elected director.
Equinor relies on the exemption provided in Rule 10A-3(b)(1)(iv)(C) from the independence requirements of the US
 
Securities
Exchange Act of 1934 with respect to the employee- elected director. Equinor does not believe that its reliance on this exemption will
materially adversely affect the ability of the audit committee to act independently or to satisfy the other
 
requirements of Rule 10A-3
relating to audit committees. The other members of the audit committee meet the independence
 
requirements under Rule 10A-3.
Among other things, the audit committee evaluates the qualifications and independence of the company’s external
 
auditor.
However, in accordance with Norwegian law, the auditor is elected by the annual general meeting of the company’s shareholders.
Equinor does not have a nominating/corporate governance committee formed from its board of directors. Instead,
 
the roles prescribed
under the NYSE rules for such committee are principally carried out by the corporate assembly and
 
the nomination committee, each of
which is elected by the general meeting of shareholders.
NYSE rules require the compensation committee of US companies to comprise independent
 
directors, recommend senior
management remuneration and determine the independence of advisors when engaging them. Equinor, as a foreign private issuer, is
exempted from complying with these rules and is permitted to follow its home country regulations.
 
Equinor considers all its
compensation committee members to be independent (under Equinor’s framework which,
 
as discussed above, is not identical to that
 
of NYSE). Equinor’s compensation committee makes recommendations to the
 
board regarding management remuneration, including
that of the CEO. Further, the compensation committee assesses its own performance and has the authority to hire external advisors.
The nomination committee, which is elected by the general meeting of shareholders, recommends to
 
the corporate assembly the
candidates and remuneration of the board of directors. The nomination committee also recommends to
 
the general meeting of
shareholders the candidates and remuneration of the corporate assembly and the nomination committee.
Shareholder approval of equity compensation plans
NYSE rules require that, with limited exemptions, all equity compensation plans must be subject to
 
a shareholder vote.
Under Norwegian company law, although the issuance of shares and authority to buy-back company shares must be approved by
Equinor’s annual general meeting of shareholders, the approval of equity compensation
 
plans is normally reserved for the board of
directors.
ITEM 16H. MINE SAFETY DISCLOSURE
Not applicable.
ITEM 16I. DISCLOSURE REGARDING FOREIGN JURISDICTIONS THAT PREVENT INSPECTIONS
Not applicable.
ITEM 17. FINANCIAL STATEMENTS
The Company has responded to Item 18 in lieu of this item
.
ITEM 18. FINANCIAL STATEMENTS
The audited consolidated financial statements as required under Item 18 are attached hereto starting on page 60 of
 
this 2022
Form 20-F. The audit report of Ernst & Young
 
AS, an independent registered accounting firm, is included herein preceding the audited
Consolidated Financial Statements.
Disclosure Pursuant to Section 13(r) of the Exchange Act
 
Equinor is providing the following disclosure pursuant to Section 13(r) of the Exchange Act.
 
Equinor entered into agreements with the National Iranian Oil Company (NIOC), namely, a Development Service Contract for
South Pars Gas Phases 6, 7 & 8 (offshore part), an Exploration Service Contract for the Anaran Block
 
and an Exploration Service
Contract for the Khorramabad Block, which are located in Iran. Equinor’s
 
operational obligations under these agreements have
terminated and the licences have been abandoned. The cost recovery programme for these contracts was
 
completed in 2012, except
for the recovery of tax and obligations to the Social Security Organization (SSO). From 2013
 
to November 2018, after closing
Equinor’s office in Iran, Equinor’s activity was focused on a final settlement with
 
the Iranian tax and SSO authorities relating to the
above-mentioned agreements.
 
In a letter from the US State Department of 1 November 2010, Equinor was informed
 
that it was not considered to be a company
of concern based on its previous Iran-related activities.
 
Equinor has an intention to settle historic obligations in Iran while remaining compliant with applicable
 
sanctions and trade
restrictions against Iran. Since November 2018 Equinor has not conducted any activity
 
in Iran, nor has it been able to resolve tax
claims from the Iranian authorities.
 
No payments were made to Iranian authorities during 2022.
 
 
 
 
 
 
ITEM 19. EXHIBITS
Exhibit no
Description
Exhibit 1
Exhibit 2.1
Exhibit 2.2
Exhibit 2.3
Exhibit 2.4
Exhibit 2.5
Exhibit 2.6
Exhibit 2.7
Exhibit 4(a)(i)
Exhibit 4(a)(ii)
Exhibit 4(c)
Exhibit 8
Exhibit 11
Exhibit 12.1
Exhibit 12.2
Exhibit 13.1
)
Exhibit 13.2
)
Exhibit 15.1
Exhibit 15.2
Exhibit 15.3
Exhibit 15.4
Exhibit 15.5
Exhibit 15.6
Exhibit 17
Exhibit 101
Interactive Data Files (formatted in Inline XBRL (Extensible Business Reporting Language)).
 
Submitted electronically
with the 2022 Form 20-
F.
Exhibit 104
Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).
1)
 
Furnished only.
The total amount of long term debt securities of Equinor ASA and its subsidiaries authorised
 
under instruments other than those listed
above does not exceed 10% of the total assets of Equinor ASA and its subsidiaries on a consolidated
 
basis. The company agrees to
furnish copies of any such instruments to the Commission upon request.
 
SIGNATURES
The registrant hereby certifies that it meets all of the requirements for filing on Form 20-F and that it
 
has duly caused and
authorised the undersigned to sign this annual report on its behalf.
EQUINOR ASA
(Registrant)
By:
 
/s/ TORGRIM REITAN
Name:
 
Torgrim Reitan
Title:
 
Executive Vice President and Chief Financial Officer
Dated: 23 March 2023
The reports set out below are provided in accordance with standards of the Public Company Accounting
 
Oversight Board (United
States). Ernst & Young AS (PCAOB ID:
1572
) has also issued a report in accordance with law, regulations, and auditing standards
and practices generally accepted in Norway, including International Standards on Auditing (ISAs), which includes opinions on the
Consolidated financial statements and the parent company financial statements of Equinor ASA, and on other
 
required matters. That
report is not included in this 2022 Form 20-F, but only in the 2022 Annual report.
Report of Independent Registered Public Accounting Firm
To the Shareholders and the Board of Directors of Equinor ASA
Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheets of Equinor ASA and its subsidiaries (Equinor
 
or the Company) as at
31 December 2022 and 2021, the related consolidated statements of income, comprehensive income,
 
changes in equity and cash
flows for each of the three years in the period ended 31 December 2022, and the related
 
notes (collectively referred to as the
“Consolidated Financial Statements”). In our opinion, the Consolidated Financial Statements
 
present fairly, in all material respects, the
financial position of the Company as at 31 December 2022 and 2021, and the results
 
of its operations and its cash flows for each of
the three years in the period ended 31 December 2022, in conformity with International Financial
 
Reporting Standards (IFRS) as
issued by the International Accounting Standards Board (IASB) and in conformity with
 
IFRS as adopted by the European Union.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United
 
States)
(PCAOB), the Company's internal control over financial reporting as at 31 December 2022, based
 
on criteria established in Internal
Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework),
and our report dated 14 March 2023 expressed an unqualified opinion thereon.
Revision of Segment Reporting
As discussed in Note 5 to the Consolidated Financial Statements, the Company
 
revised the measurement basis for the segments
related to leases. The revision has been retrospectively adjusted for the years ended
 
31 December 2021 and 2020.
Basis for Opinion
These financial statements are the responsibility of the Company's management. Our responsibility
 
is to express an opinion on the
Company’s financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to
be independent with respect to the Company in accordance with the U.S. federal securities
 
laws and the applicable rules and
regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require
 
that we plan and perform the
audit to obtain reasonable assurance about whether the Consolidated Financial Statements are
 
free of material misstatement,
whether due to error or fraud. Our audits included performing procedures to assess the risks
 
of material misstatement of the
Consolidated Financial Statements, whether due to error or fraud, and performing procedures that
 
respond to those risks. Such
procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the Consolidated
 
Financial
Statements. Our audits also included evaluating the accounting principles used and significant
 
estimates made by management, as
well as evaluating the overall presentation of the Consolidated Financial Statements. We believe that our audits
 
provide a reasonable
basis for our opinion.
Critical Audit Matters
The critical audit matters communicated below are matters arising from the current period
 
audit of the Consolidated Financial
Statements that were communicated to the audit committee and that: (1) relate to accounts or disclosures
 
that are material to the
Consolidated Financial Statements and (2) involved our especially challenging, subjective or complex judgments. The
 
communication
of critical audit matters does not alter in any way our opinion on the Consolidated Financial Statements,
 
taken as a whole, and we are
not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the accounts
 
or
disclosures to which they relate.
Recognition of deferred tax asset related to the US filing jurisdiction
Description of the
Matter
As at 31 December 2022, the Company has recognised a previously unrecognised deferred tax
asset of USD 2,738 million related to the US filing jurisdiction, which requires convincing
 
evidence
through future taxable profit to support the probable realisation of the deferred tax asset against
historical carry-forward tax losses. Refer to Note 11 to the Consolidated Financial Statements for the
related disclosures. As described in Note 11, deferred tax assets are recognised based on the
expectation that sufficient taxable income will be available through reversal of taxable temporary
differences or future taxable income. The future taxable income has to be considered probable
based on business forecasts.
In addition to agreeing the historical losses to supporting documentation, auditing management’s
estimate of the amount of the deferred tax asset is subjective because the estimation requires
significant judgement, including the timing of reversals of the deferred tax liability and the availability
of future profits against which tax deductions represented by the deferred tax asset can
 
be offset. In
addition, auditing management’s estimate of amount of the deferred tax balances that are supported
by the expectation of future taxable profits requires a high degree of judgement. Significant
assumptions used in future taxable profits are commodity prices, expected oil and gas reserves
 
and
capital expenditures.
These significant assumptions are forward-looking and are heightened in complexity given the future
demand and price uncertainty due to climate change and the energy transition. As described
 
in Note
3 to the Consolidated Financial Statements, the effects of the initiatives to limit climate changes
 
and
the potential impact of the energy transition are relevant to some of the economic assumptions in
 
the
Company’s estimation of future cash flows. Climate considerations are included directly in the
deferred tax asset assessments by estimating the CO
2
 
costs in the cash flows, and indirectly as the
expected effects of the climate change are included in the estimated commodity prices. Commodity
price assumptions applied in the recognition of deferred tax assets are based on management’s best
estimate, which differs from the price-set required to achieve the goals of the Paris Agreement as
described in the International Energy Agency (IEA) World Energy Outlook’s Announced Pledges
Scenario, or the Net Zero Emissions by 2050 Scenario. The impact of the energy transition
 
and
potential restrictions by regulators, market and strategic considerations may also have an effect on
the estimated production profiles and the economic lifetime of the Company’s US assets and
projects.
How We Addressed the
Matter in Our Audit
We obtained an understanding, evaluated the design, and tested the operating effectiveness of
controls over the Company’s process for the recognition of the deferred tax asset related to the US
filing jurisdiction. This included testing controls over the Company’s process for tracking tax loss
carry-forwards, management’s review of assumptions and inputs to the calculations of future taxable
profit and scheduling of reversal of the deferred tax liabilities.
In assessing the recognition and measurement of the deferred taxes we tested the completeness
and accuracy of the amounts recognised as deferred tax asset by verifying tax loss
 
carry-forwards
against historical tax filings and assessing management’s determination of the expected timing
 
of
utilisation of the deferred tax asset, including the application of relevant tax laws to the utilisation
 
of
tax losses. We also evaluated management’s forecasted timing of the reversal of taxable temporary
differences by considering the nature of the temporary differences and the relevant tax law. We
involved our US tax specialists to assist us in these procedures.
Our audit procedures performed over the significant assumptions and inputs included, among others,
evaluation of the methods and models used in the calculation of future taxable profit. We compared
projected capital expenditures, from which depreciation expense is derived, and expected reserve
volumes used in the estimation of the future taxable profit to approved operator budgets or
management forecasts, and also compared expected reserve volumes to external evaluations when
available. In addition, we compared the forecast to that used in other areas of analysis,
 
such as
impairment or impairment reversal assessment, as applicable.
To test price assumptions, we evaluated management’s methodology to determine future commodity
prices and compared such assumptions to external benchmarks, among other procedures. We
evaluated management’s methodology to factor climate-related matters into their determination of
future commodity prices.
To test carbon costs assumptions, with the involvement of climate change and sustainability
specialists, we evaluated management’s methodology to determine future CO
2
 
tax, including
assessing the impact from climate-related matters, through comparison of management’s
assumptions with the current legislation in place and the jurisdiction’s announced pledges regarding
escalation of CO
2
 
taxes.
We assessed management’s sensitivity analysis disclosed in Note 11 related to a reasonably
possible change in commodity prices.
Recoverable amounts of production plants and oil and gas assets including assets under
 
development
 
Description of the Matter
As at 31 December 2022, the Company has recognised production plants and oil and gas
 
assets,
including assets under development, of USD 40,493 million and USD 10,679 million, respectively,
within Property, plant and equipment. Refer to Note 14 to the Consolidated Financial Statements for
the related disclosures. As described in Note 14, determining the recoverable
 
amount of an asset
involves an estimate of future cash flows, which is dependent upon management’s best estimate of the
economic conditions that will exist over the asset’s useful life. The asset’s operational performance
and external factors have a significant impact on the estimated future cash flows and therefore, the
recoverable amount of the asset.
Auditing management’s estimate of the recoverable amount of production plants and oil and gas
assets is complex and involves a high degree of judgement. Significant assumptions used in
forecasting future cash flows are future commodity prices, currency exchange rates, expected
reserves, capital expenditures, and the discount rate.
These significant assumptions are forward-looking and can be affected by future economic and market
conditions, including matters related to climate change and energy transition. As described
 
in Note 3 to
the Consolidated Financial Statements, the effects of the initiatives to limit climate changes and the
potential impact of the energy transition are relevant to some of the economic assumptions in the
Company’s estimation of future cash flows. Climate considerations are included directly in the
impairment assessments by estimating the CO
2
 
costs in the cash flows, and indirectly as the expected
effects of the climate change are included in the estimated commodity prices. As also described
 
in
Note 3, commodity price assumptions applied in value-in-use impairment testing are based on
management’s best estimate, which differs from the price-set required to achieve the goals of the Paris
Agreement as described in the International Energy Agency (IEA) World Energy Outlook’s Announced
Pledges Scenario, or the Net Zero Emissions by 2050 Scenario. The impact of the energy transition
and potential restrictions by regulators, market and strategic considerations may also
 
have an effect
on the estimated production profiles and the economic lifetime of the Company’s assets and projects.
Additionally, the treatment of tax in the estimation of the recoverable amount is challenging, as the
Company is subject to different tax structures that are inherently complex, particularly in Norway.
 
How We Addressed the
 
 
Matter in Our Audit
We obtained an understanding, evaluated the design, and tested the operating effectiveness of
controls over the Company’s process for evaluating the recoverability of production plants and oil and
gas assets including assets under development. This included testing controls over management’s
review of assumptions and inputs to the assessments of impairment and impairment reversals.
Our audit procedures performed over the significant assumptions and inputs included, among others,
evaluation of the methods and models used in the calculation of the recoverable amount. We also
evaluated the relevant tax effects based on the local legislation of the relevant jurisdictions, particularly
in Norway, and tested the clerical accuracy of the models through independently recalculating the
value in use. We involved valuation specialists to assist us with these procedures. In addition, we
compared projected capital expenditures to approved operator budgets or management forecasts and
compared expected reserve volumes to internal production forecasts and external evaluations of
expected reserves, in accordance with the Company’s internal procedures. For those assets
previously impaired, we compared actual results to the forecasts used in historical impairment
analyses. We also involved reserves specialists to assist us with these procedures.
To test price assumptions, we evaluated management’s methodology to determine future commodity
prices and compared such assumptions to external benchmarks, among other procedures. We
involved valuation specialists to assist in evaluating the reasonableness of the Company’s assessment
of currency exchange rates and the discount rate, by assessing the Company’s methodologies and
key assumptions used to calculate the rates and by comparing those rates with external information.
We also evaluated management’s methodology to factor climate-related matters into their
determination of future commodity prices, through assessing management’s sensitivity analyses as
discussed below.
To test carbon costs assumptions, with the involvement of climate change and sustainability
specialists, we evaluated management’s methodology to determine future CO
2
 
tax, including
assessing the impact from climate-related matters, through assessing management’s sensitivity
analyses as discussed below, and compared management’s assumptions with the current legislation
in place in the relevant jurisdictions and the jurisdictions’ announced pledges regarding escalation
 
of
CO
2
 
taxes.
We evaluated management’s sensitivity analyses over its future commodity prices and carbon cost
assumptions by taking into consideration, among other sources, the Net Zero Emissions by 2050
Scenario and Announced Pledges Scenario estimated by the International Energy Agency
 
(IEA). We
have also evaluated management’s disclosures related to the consequences of initiatives to limit
climate changes, including the effects of the Company’s climate change strategy on the Consolidated
Financial Statements and the energy transition’s effects on estimation uncertainty, discussed in more
detail in Notes 3 and 14.
Estimation of the asset retirement obligations
 
Description of the Matter
As at 31 December 2022, the Company has recognised a provision for decommissioning and
 
removal
activities of USD 11,734 million classified within Provisions and other liabilities. Refer to Note 23 to the
Consolidated Financial Statements for disclosures. As described in Note 23, the appropriate estimates
for such obligations are based on historical knowledge combined with knowledge of ongoing
technological developments, expectations about future regulatory and technological development and
involve the application of judgement and an inherent risk of significant adjustments. The estimated
costs of decommissioning and removal activities require revisions due to changes in current
regulations and technology while considering relevant risks and uncertainties.
Auditing management’s estimate of the decommissioning and removal of offshore installations at the
end of the production period is complex and involves a high degree of judgement. Determining the
provision for such obligation involves application of considerable judgement related to the
 
assumptions
used in the estimate, the inherent complexity and uncertainty in estimating future costs,
 
and the limited
historical experience against which to benchmark estimates of future costs. Significant assumptions
used in the estimate are the discount rates and the expected future costs, which include the underlying
assumptions norms and rates and time required to decommission and can vary considerably
depending on the expected removal complexity.
These significant assumptions are forward-looking and can be affected by future economic and market
conditions, including matters related to climate change and energy transition. As described
 
in Note 3 to
the Consolidated Financial Statements, the effects of the initiatives to limit climate changes and the
potential impact of the energy transition are relevant to some of the economic assumptions in the
Company’s estimation of future cash flows. The impact of the energy transition and potential
restrictions by regulators, market and strategic considerations may also have an effect on the
estimated economic lifetime of the Company’s assets and projects. If the Company’s business cases
for the oil and gas producing assets in the future should change materially due to governmental
initiatives to limit climate change, it could affect the timing of cessation of the assets and the
 
asset
retirement obligations (ARO).
How We Addressed the
 
Matter in Our Audit
We obtained an understanding, evaluated the design, and tested the operating effectiveness of
controls over the Company’s process to calculate the present value of the estimated future
decommissioning and removal activities determined in accordance with local conditions and
requirements. This includes controls related to management’s review of assumptions described above,
used in the calculation of the ARO.
To test management’s estimation of the provision for decommissioning and removal activities, our
audit procedures included, among others, evaluating the completeness of the provision by comparing
significant additions to property, plant and equipment to management’s assessment of new ARO
obligations recognized in the period.
To assess the expected future costs, among other procedures, we compared day rates for rigs, marine
operations and heavy lift vessels to external market data or existing contracts. For time required
 
to
decommission, we compared the assumptions against historical data on a sample basis. We
compared discount rates to external market data. With the support of our valuation specialists,
 
we
evaluated the methodology and models used by management to estimate the ARO
 
and performed a
sensitivity analysis on the significant assumptions. In addition, we recalculated the formulas in the
models.
We recalculated management’s sensitivity analyses over the effect of performing removal five years
earlier than currently scheduled due to potential governmental initiatives to limit climate changes.
We have also evaluated management’s disclosures related to the consequences of initiatives to limit
climate changes, including the effects of the Company’s climate change strategy on the Consolidated
Financial Statements and the energy transition’s effects on estimation uncertainty, discussed in more
detail in Notes 3 and 23.
/s/
Ernst & Young AS
We have served as the Company’s auditor since 2019.
Stavanger, Norway
14 March 2023
Report of Independent Registered Public Accounting Firm
To the Shareholders and the Board of Directors of Equinor ASA
Opinion on Internal Control over Financial Reporting
We have audited Equinor ASA and subsidiaries’ (the Company) internal control over financial reporting
 
as at 31 December 2022,
based on criteria established in Internal Control—Integrated Framework issued by the Committee
 
of Sponsoring Organizations of the
Treadway Commission (2013 framework) (the COSO criteria). In our opinion, the Company maintained, in all material
 
respects,
effective internal control over financial reporting as at 31 December 2022, based on the COSO criteria.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States)
(PCAOB), the 2022 Consolidated Financial Statements of the Company, and our report dated 14 March 2023 expressed an
unqualified opinion thereon.
Basis for Opinion
The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment
 
of
the effectiveness of internal control over financial reporting included in the accompanying Management's Report
 
on Internal Control
over Financial Reporting as set out in Item 15. Controls and Procedures. Our responsibility
 
is to express an opinion on the Company’s
internal control over financial reporting based on our audit. We are a public accounting firm registered with
 
the PCAOB and are
required to be independent with respect to the Company in accordance with the U.S. federal
 
securities laws and the applicable rules
and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan
 
and perform the audit
to obtain reasonable assurance about whether effective internal control over financial reporting was maintained
 
in all material
respects. Our audit included obtaining an understanding of internal control over financial reporting,
 
assessing the risk that a material
weakness exists, testing and evaluating the design and operating effectiveness of internal control based
 
on the assessed risk, and
performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides
 
a reasonable
basis for our opinion.
Definition and Limitations of Internal Control over Financial Reporting
A company’s internal control over financial reporting is a process designed to provide reasonable
 
assurance regarding the reliability of
financial reporting and the preparation of financial statements for external purposes in accordance with
 
generally accepted accounting
principles. A company’s internal control over financial reporting includes those policies and procedures that (1)
 
pertain to the
maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and
 
dispositions of the assets of the
company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation
 
of financial statements
in accordance with generally accepted accounting principles, and that receipts and expenditures
 
of the company are being made only
in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance
 
regarding
prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could
 
have a material effect
on the financial statements.
 
Because of its inherent limitations, internal control over financial reporting may not prevent or
 
detect misstatements. Also, projections
of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because
 
of changes in
conditions, or that the degree of compliance with the policies or procedures may deteriorate.
/s/ Ernst & Young AS
Stavanger, Norway
14 March 2023
60
 
Equinor, Annual Report on Form 20-F 2022
 
Consolidated financial statements of the Equinor group
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
61
CONSOLIDATED STATEMENT
 
OF INCOME
Full year
(in USD million)
Note
2022
2021
2020
Revenues
7
149,004
88,744
45,753
Net income/(loss) from equity accounted investments
15
620
259
53
Other income
6
1,182
1,921
12
 
Total revenues and other income
7
150,806
90,924
45,818
 
Purchases [net of inventory variation]
 
(53,806)
(35,160)
(20,986)
Operating expenses
 
(9,608)
(8,598)
(8,831)
Selling, general and administrative expenses
 
(986)
(780)
(706)
Depreciation, amortisation and net impairment losses
12, 13
(6,391)
(11,719)
(15,235)
Exploration expenses
13
(1,205)
(1,004)
(3,483)
Total operating expenses
9
(71,995)
(57,261)
(49,241)
Net operating income/(loss)
5
78,811
33,663
(3,423)
Interest expenses and other finance expenses
(1,379)
(1,223)
(1,392)
Other financial items
1,172
(857)
556
Net financial items
10
(207)
(2,080)
(836)
 
Income/(loss) before tax
78,604
31,583
(4,259)
Income tax
11
(49,861)
(23,007)
(1,237)
Net income/(loss)
 
28,744
8,576
(5,496)
 
Attributable to equity holders of the company
 
28,746
8,563
(5,510)
Attributable to non-controlling interests
 
(3)
14
14
Basic earnings per share (in USD)
9.06
2.64
(1.69)
Diluted earnings per share (in USD)
9.03
2.63
(1.69)
Weighted average number of ordinary shares outstanding
 
(in millions)
3,174
3,245
3,269
Weighted average number of ordinary shares outstanding, diluted
 
(in millions)
3,183
3,254
3,277
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
62
 
Equinor, Annual Report on Form 20-F 2022
 
CONSOLIDATED STATEMENT
 
OF COMPREHENSIVE INCOME
Full year
(in USD million)
Note
2022
2021
2020
Net income/(loss)
 
28,744
8,576
(5,496)
Actuarial gains/(losses) on defined benefit pension
 
plans
461
147
(106)
Income tax effect on income and expenses recognised
 
in OCI
1)
(105)
(35)
19
Items that will not be reclassified to the Consolidated
 
statement of income
22
356
111
(87)
Foreign currency translation effects
(3,609)
(1,052)
1,064
Share of OCI from equity accounted investments
424
0
0
Items that may subsequently be reclassified to the Consolidated
 
statement of income
(3,186)
(1,052)
1,064
Other comprehensive income/(loss)
(2,829)
(940)
977
Total comprehensive income/(loss)
25,914
7,636
(4,519)
Attributable to the equity holders of the company
25,917
7,622
(4,533)
Attributable to non-controlling interests
(3)
14
14
1) Other Comprehensive Income (OCI).
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
63
CONSOLIDATED BALANCE SHEET
 
At 31 December
(in USD million)
Note
2022
2021
ASSETS
Property, plant and equipment
12
56,498
62,075
Intangible assets
13
5,158
6,452
Equity accounted investments
15
2,758
2,686
Deferred tax assets
11
8,732
6,259
Pension assets
22
1,219
1,449
Derivative financial instruments
28
691
1,265
Financial investments
16
2,733
3,346
Prepayments and financial receivables
16
2,063
1,087
Total non-current assets
 
79,851
84,618
Inventories
17
5,205
3,395
Trade and other receivables
1)
18
22,452
17,927
Derivative financial instruments
28
4,039
5,131
Financial investments
16
29,876
21,246
Cash and cash equivalents
2)
19
15,579
14,126
 
Total current assets
 
77,152
61,826
 
Assets classified as held for sale
6
1,018
676
Total assets
 
158,021
147,120
EQUITY AND LIABILITIES
Shareholders’ equity
 
53,988
39,010
Non-controlling interests
 
1
14
Total equity
20
53,989
39,024
Finance debt
21
24,141
27,404
Lease liabilities
25
2,409
2,449
Deferred tax liabilities
11
11,996
14,037
Pension liabilities
22
3,671
4,403
Provisions and other liabilities
23
15,633
19,899
Derivative financial instruments
28
2,376
767
Total non-current liabilities
 
60,226
68,959
Trade, other payables and provisions
24
13,352
14,310
Current tax payable
 
17,655
13,119
Finance debt
21
4,359
5,273
Lease liabilities
25
1,258
1,113
Dividends payable
20
2,808
582
Derivative financial instruments
28
4,106
4,609
Total current liabilities
 
43,539
39,005
 
Liabilities directly associated with the assets classified
 
as held for sale
6
268
132
Total liabilities
 
104,032
108,096
Total equity and liabilities
 
158,021
147,120
64
 
Equinor, Annual Report on Form 20-F 2022
 
1)
 
Of which Trade receivables of USD
17,334
 
million in 2022 and USD
15,237
 
million in 2021.
2)
 
Includes collateral deposits of USD
6,128
 
million for 2022 related to certain requirements
 
set out by exchanges where Equinor is
participating. The corresponding figure for 2021 is
 
USD
2,069
 
million.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
65
CONSOLIDATED STATEMENT
 
OF CHANGES IN EQUITY
(in USD million)
Share
capital
Additional
paid-in
capital
Retained
earnings
Foreign
currency
translation
reserve
OCI from equity
accounted
investments
1)
Shareholders'
equity
Non-
controlling
interests
Total equity
At 1 January 2020
1,185
7,732
37,481
(5,258)
0
41,139
20
41,159
Net income/(loss)
(5,510)
(5,510)
14
(5,496)
Other comprehensive income/(loss)
(87)
1,064
977
977
Total comprehensive income/(loss)
(4,519)
Dividends
(1,833)
(1,833)
(1,833)
Share buy-back
(21)
(869)
(890)
(890)
Other equity transactions
(11)
(11)
(15)
(25)
At 31 December 2020
1,164
6,852
30,050
(4,194)
0
33,873
19
33,892
Net income/(loss)
8,563
8,563
14
8,576
Other comprehensive income/(loss)
111
(1,052)
(940)
(940)
Total comprehensive income/(loss)
7,636
Dividends
(2,041)
(2,041)
(2,041)
Share buy-back
(429)
(429)
(429)
Other equity transactions
(15)
(15)
(18)
(33)
At 31 December 2021
1,164
6,408
36,683
(5,245)
0
39,010
14
39,024
Net income/(loss)
28,746
28,746
(3)
28,744
Other comprehensive income/(loss)
356
(3,609)
424
(2,829)
(2,829)
Total comprehensive income/(loss)
25,914
Dividends
(7,549)
(7,549)
(7,549)
Share buy-back
(22)
(3,358)
(3,380)
(3,380)
Other equity transactions
(10)
(10)
(10)
(20)
At 31 December 2022
1,142
3,041
58,236
(8,855)
424
53,988
1
53,989
1)
 
OCI items from equity accounted investments
 
that may subsequently be reclassified to the Consolidated
 
statement of income, are
presented as part of OCI from equity accounted
 
investments. OCI items that will not be reclassified
 
to the Consolidated statements of income
will be included in retained earnings.
 
Please refer to note 20 Shareholders’ equity
 
and dividends for more details.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
66
 
Equinor, Annual Report on Form 20-F 2022
 
CONSOLIDATED STATEMENT
 
OF CASH FLOWS
Full year
(in USD million)
Note
2022
2021
2020
Income/(loss) before tax
78,604
31,583
(4,259)
Depreciation, amortisation and net impairment
12, 13
6,391
11,719
15,235
Exploration expenditures written off
13
342
171
2,506
(Gains)/losses on foreign currency transactions and
 
balances
(2,088)
(47)
646
(Gains)/losses on sale of assets and businesses
6
(823)
(1,519)
18
(Increase)/decrease in other items related to operating
 
activities
1)
468
106
918
(Increase)/decrease in net derivative financial instruments
28
1,062
539
(451)
Interest received
399
96
162
Interest paid
(747)
(698)
(730)
Cash flows provided by operating activities before
 
taxes paid and working capital items
83,608
41,950
14,045
Taxes paid
(43,856)
(8,588)
(3,134)
(Increase)/decrease in working capital
(4,616)
(4,546)
(524)
Cash flows provided by operating activities
 
35,136
28,816
10,386
Capital expenditures and investments
6
(8,611)
(8,151)
(8,476)
(Increase)/decrease in financial investments
(10,089)
(9,951)
(3,703)
(Increase)/decrease in derivative financial instruments
1,894
(1)
(620)
(Increase)/decrease in other interest-bearing items
(23)
28
202
Proceeds from sale of assets and businesses
6
966
1,864
505
Cash flows provided by/(used in) investing activities
(15,863)
(16,211)
(12,092)
New finance debt
21
0
0
8,347
Repayment of finance debt
21
(250)
(2,675)
(2,055)
Repayment of lease liabilities
25
(1,366)
(1,238)
(1,277)
Dividends paid
20
(5,380)
(1,797)
(2,330)
Share buy-back
20
(3,315)
(321)
(1,059)
Net current finance debt and other financing activities
(5,102)
1,195
1,365
Cash flows provided by/(used in) financing activities
21
(15,414)
(4,836)
2,991
Net increase/(decrease) in cash and cash equivalents
3,860
7,768
1,285
Foreign currency translation effects
(2,268)
(538)
294
Cash and cash equivalents at the beginning of
 
the period (net of overdraft)
19
13,987
6,757
5,177
Cash and cash equivalents at the end of the
 
period (net of overdraft)
2)
19
15,579
13,987
6,757
1)
 
The line item mainly consists of provisions, unrealised
 
gains and losses and items of income
 
or expense for which the cash effects are
included in increase/(decrease) in working capital within
 
operating cash flow and investing cash flows.
 
The line item includes a fair value
loss related to inventory of USD
672
 
million at 31 December 2022.
 
Amount for 2021 includes MUSD (
822
) redetermination settlement for
the Agbami field.
 
2)
 
At 31 December 2022 cash and cash equivalents
 
net overdraft was
zero
. At 31 December 2021 cash and cash equivalents
 
included a net
overdraft of USD
140
 
million and at 31 December 2020 net overdraft
 
were
zero
.
Interest paid
in cash flows provided by operating activities
 
excludes capitalised interest of USD
382
 
million, USD
334
 
million, and USD
308
million for the years ending 31 December 2022, 2021
 
and 2020, respectively. Capitalised interest is included in Capital expenditures
 
and
investments in cash flows used in investing activities.
 
Total interest paid amounts to USD
1,129
 
million, USD
1,032
 
million, and USD
1,038
million for the years 2022, 2021 and 2020, respectively.
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
67
Notes to the Consolidated financial statements
Table of contents for notes to the financial statements
1
Organisation
2
Accounting policies
3
Consequences of initiatives to limit climate changes
4
Financial risk and capital management
5
Segments
6
Acquisitions and disposals
7
Total revenues and other income
8
Salaries and personnel expenses
9
Auditor’s remuneration and Research and development expenditures
10
Financial items
11
Income taxes
12
Property, plant and equipment
13
Intangible assets
14
Impairments
15
Joint arrangements and associates
16
Financial investments and financial receivables
17
Inventories
18
Trade and other receivables
19
Cash and cash equivalents
20
Shareholders’ equity and dividends
21
Finance debt
22
Pensions
23
Provisions and other liabilities
24
Trade, other payables and provisions
25
Leases
26
Other commitments, contingent liabilities and contingent assets
27
Related parties
28
Financial instruments and fair value measurement
29
Subsequent events
68
 
Equinor, Annual Report on Form 20-F 2022
 
1 Organisation
The Equinor Group (Equinor) consists of Equinor ASA and its subsidiaries.
Equinor ASA
 
is incorporated and domiciled in
Norway
 
and
listed on the Oslo Børs (
Norway
) and the New York Stock Exchange (USA). The address of its registered office is
Forusbeen 50, N-
4035 Stavanger, Norway
.
Equinor’s objective is to develop, produce and market various forms of energy and derived products and services, as well as other
business. The activities may also be carried out through participation in or cooperation with other companies.
 
Equinor Energy AS, a
100
% owned operating subsidiary of Equinor ASA and owner of all of Equinor's oil
 
and gas activities and net assets on the Norwegian
continental shelf, is co-obligor or guarantor for certain debt obligations of Equinor ASA.
The Consolidated financial statements of Equinor for the full year 2022 were approved for issuance
 
by the board of directors on 14
March 2023 and is subject to approval by the annual general meeting on 10 May 2023.
2 Accounting policies
Statement of compliance
The Consolidated financial statements of Equinor ASA and its subsidiaries (Equinor) have been prepared in
 
accordance with
International Financial Reporting Standards (IFRS) as adopted by the European Union (EU) and
 
with IFRSs as issued by the
International Accounting Standards Board (IASB), interpretations issued by IASB and the additional
 
requirements of the Norwegian
Accounting Act, effective on 31 December 2022.
Basis of preparation
The Consolidated financial statements are prepared on the historical cost basis with some exceptions where fair
 
value measurement
is applied. These exceptions are specifically disclosed in the accounting policies sections in relevant notes. The
 
material accounting
policies described in these Consolidated financial statements have been applied consistently to
 
all periods presented, except as
otherwise noted in the disclosure related to the impact of policy changes following the
 
adoption of new accounting standards and
voluntary changes in 2022.
Certain amounts in the comparable years have been restated or reclassified to conform to current
 
year presentation. All amounts in
the Consolidated financial statements are denominated in USD millions, unless otherwise specified. The subtotals
 
and totals in some
of the tables in the notes may not equal the sum of the amounts shown in the primary
 
financial statements due to rounding.
Operational expenses in the Consolidated statement of income are presented as a combination
 
of function and nature in conformity
with industry practice. Purchases [net of inventory variation] and Depreciation, amortisation and net impairment
 
losses are presented
on separate lines based on their nature, while Operating expenses and Selling, general
 
and administrative expenses as well as
Exploration expenses are presented on a functional basis. Significant expenses such as salaries, pensions, etc.
 
are presented by their
nature in the notes to the Consolidated financial statements.
Basis of consolidation
The Consolidated financial statements include the accounts of Equinor ASA and its subsidiaries
 
as well as Equinor’s interests in jointly
controlled and equity accounted investments. All intercompany balances and transactions, including unrealised
 
profits and losses
arising from Equinor's internal transactions, have been eliminated.
The Consolidated financial statements include all entities controlled by Equinor ASA. Entities are
 
determined to be controlled by
Equinor when Equinor has power over the entity, ability to use that power to affect the entity's returns, and exposure to, or rights to,
variable returns from its involvement with the entity. The financial statements of the subsidiaries are included in the Consolidated
financial statements from the date control is achieved until the date control ceases.
Non-controlling interests are presented separately within equity in the Consolidated balance sheet.
Foreign currency translation
In preparing the financial statements of the individual entities in Equinor, transactions in currencies other than the functional currency
are translated at the foreign exchange rate at the dates of the transactions. Monetary
 
assets and liabilities denominated in foreign
currencies are translated to the functional currency at the foreign exchange rate at the
 
balance sheet date. Foreign exchange
differences arising on translation are recognised in the Consolidated statement of income as foreign exchange
 
gains or losses within
Net financial items. However, foreign exchange differences arising from the translation of estimate-based provisions are generally
accounted for as part of the change in the underlying estimate and included within the relevant
 
operating expense or income tax line-
items depending on the nature of the provision. Non-monetary assets measured at historical cost
 
in a foreign currency are translated
using the exchange rate at the date of the transactions.
Equinor, Annual Report on Form 20-F 2022
 
69
When preparing the Consolidated financial statements, the assets and liabilities of entities with functional
 
currencies other than the
Group’s presentation currency USD are translated into USD at the foreign exchange rate at the balance
 
sheet date. The revenues and
expenses of such entities are translated using the foreign exchange rates on the dates of the
 
transactions. Foreign exchange
differences arising on translation from functional currency to USD are recognised separately in the
 
Consolidated statement of
comprehensive income within Other comprehensive income (OCI). The cumulative amount of such
 
translation differences relating to
an entity is reclassified to the Consolidated statement of income and reflected as a part of the
 
gain or loss on disposal of that entity.
Loans from Equinor ASA to subsidiaries and equity accounted investments with other functional
 
currencies than the parent company,
and for which settlement is neither planned nor likely in the foreseeable future, are considered part
 
of the parent company’s net
investment in the subsidiary. Foreign exchange differences arising on such loans are recognised in OCI in the Consolidated financial
statements.
Statement of cash flows
In the statement of cash flows, operating activities are presented using the indirect method, where Income/(loss)
 
before tax is adjusted
for changes in inventories and operating receivables and payables, the effects of non-cash items such as depreciations,
 
amortisations
and impairments, provisions, unrealised gains and losses and undistributed profits from associates, and items
 
of income or expense
for which the cash effects are investing or financing cash flows. Increase/decrease in financial investments,
 
Increase/decrease in
derivative financial instruments, and Increase/decrease in other interest-bearing items are all presented
 
net as part of Investing
activities, either because the transactions are financial investments and turnover is quick, the amounts
 
are large, and the maturities
are short, or due to materiality.
--------------------------------------------------------------------------------------------------------------------------------
Accounting judgement and key sources of estimation uncertainty
The preparation of the Consolidated financial statements requires management to make accounting
 
judgements, estimates and
assumptions affecting reported amounts of assets, liabilities, income and expenses.
The main areas where Equinor has made significant judgements
 
when applying the accounting policies and that have the most
material effect on the amounts recognised in the Consolidated financial statements have been described in
 
the following notes:
6 – Acquisitions and disposals
7 – Total revenues and other income
25 – Leases
Estimates used in the preparation of these Consolidated financial statements are prepared based on customised models,
 
while the
assumptions on which the estimates are based rely on historical experience, external sources of information
 
and various other factors
that management assesses to be reasonable under the current conditions and circumstances. These
 
estimates and assumptions form
the basis of making the judgements about carrying values of assets and liabilities
 
when these are not readily apparent from other
sources. Actual results may differ from these estimates. The estimates and underlying assumptions are reviewed on an
 
on-going
basis considering the current and expected future set of conditions.
Equinor is exposed to several underlying economic factors affecting the overall results, such as commodity
 
prices, foreign currency
exchange rates, market risk premiums and interest rates as well as financial instruments with
 
fair values derived from changes in
these factors. The effects of the initiatives to limit climate changes and the potential impact of the energy transition
 
are relevant to
several of these economic assumptions. In addition, Equinor's results are influenced by the level
 
of production, which in the short term
may be influenced by, for instance, maintenance programmes. In the long-term, the results are impacted by the success of
exploration, field developments and operating activities.
The most important matters in understanding the key sources of estimation uncertainty are
 
described in each of the following notes:
3 – Consequences of initiatives to limit climate changes
11 – Income taxes
12 – Property, plant and equipment
13 – Intangible assets
14 – Impairments
23 – Provisions and other liabilities
26 – Other commitments, contingent liabilities and contingent assets
--------------------------------------------------------------------------------------------------------------------------------
Changes in accounting policies in the current period
Amendments to IAS 1 and IFRS practice statement 2: Replacing Significant accounting policies with Material
 
accounting
policies
IASB has issued amendments to IAS 1 Presentation of financial statements and IFRS
 
Practice Statement 2 Making Materiality
Judgements. These amendments are intended to help entities apply materiality judgements to accounting
 
policy disclosures and
provide additional guidance and illustrative examples. The amendments are effective for annual periods beginning on or
 
after 1
 
 
 
 
 
70
 
Equinor, Annual Report on Form 20-F 2022
 
January 2023. Earlier application is permitted, and Equinor has applied the amendments with
 
effect from these Consolidated financial
statements.
Accounting policy information should be considered material if its disclosure can reasonably be
 
expected to influence user decisions
and therefore is needed to understand other information provided about material transactions, other
 
events, or conditions in the
financial statements. IASB has acknowledged that standardised information, or information that only duplicates
 
or summarises the
requirements of the IFRS -standards, is generally less useful than entity-specific accounting policy information.
 
Even though such
information could be material in specific circumstances, Equinor has focused the accounting policy
 
disclosures on Equinor-specific
policy choices, disclosing only those accounting policies that are considered necessary to understand other material
 
information in the
Consolidated financial statements of Equinor.
Other standards, amendments to standards and interpretations of standards, effective
 
as of 1 January 2022
Other amendments to standards or interpretations of standards effective as of 1 January 2022 and adopted
 
by Equinor, were not
material to Equinor’s Consolidated financial statements upon adoption.
Other standards, amendments to standards, and interpretations of standards, issued but not yet effective, are either
 
not expected to
materially impact, or are not expected to be relevant to, Equinor's Consolidated financial statements upon
 
adoption.
3 Consequences of initiatives to limit climate changes
Accounting policies - c
ost of CO
2
 
quotas
Purchased CO
2
 
quotas under the EU Emissions Trading System (EU ETS) are reflected at cost in Operating expenses as
incurred in line with emissions. Accruals for CO
2
 
quotas required to cover emissions to date are valued at market price and
reflected as a current liability within Trade, other payables and provisions. Quotas owned, but exceeding the emissions
incurred to date, are carried in the balance sheet at cost price, classified as Other current receivables, as long as such
purchased quotas are acquired in order to cover own emissions and may be kept to cover subsequent years’ emissions.
Quotas purchased and held for trading purposes are carried in the balance sheet at fair value, and the changes in fair value
are reflected in the Consolidated statement of income on the line-item Other income.
Obligations resulting from current year emissions and the corresponding amounts for quotas that have been bought, paid and
expensed, but which have not yet been surrendered to the relevant authorities, are reflected net in the balance sheet.
 
----------------------------------------------------------------------------------------------------------------------------------------
Equinor’s strategy and ambitions
Equinor’s ambition is to continue supplying society with energy with lower emissions
 
over time, to be a leading company in the energy
transition and becoming a net-zero company by 2050, including emissions from production through to final
 
energy consumption.
Equinor’s strategy is to create value as a leader in the energy transition by pursuing
 
high-value growth in renewables and new market
opportunities in low carbon solutions at the same time as we optimise our oil and gas
 
portfolio. This strategy covers three strategically
important and interconnected areas:
●
 
Oil and gas. Equinor’s main focus is optimising our resources, cutting emissions in
 
our operations and identifying new procedures
that enable us to continue supplying energy that the world needs with a low footprint.
●
 
Renewables. There is an apparent global demand for more renewable energy, and Equinor’s investments in offshore wind and
solar are growing exponentially to meet this demand.
●
 
Low carbon solutions. Equinor will continue its investments in new technologies and value chains
 
for producing lower emissions
by replacing the use of carbon when generating new energy or capturing and removing the greenhouse
 
gases before they reach
the atmosphere. Even though carbon capture and storage (CCS) has existed as a technology for many decades,
 
it takes time to
develop the value chains and carbon capture and storage has yet to be implemented
 
as a revenue-generating service to the
market on a full scale.
Risks arising from climate change and the transition to a lower carbon economy
Policy, legal, regulatory,
 
market and technology developments related to the issue of climate change, can affect our business plans
and financial performance. Shifts in stakeholder focus between energy security, affordability and sustainability add uncertainty to
delivery and outcomes associated with Equinor’s strategy. Equinor’s long-term plans have to consider how the global
 
energy markets
may develop in the long term. Potential scenarios of future changes in demand for our
 
products (oil, gas and power in key markets)
are analysed, including World Energy Outlook 2022 (WEO) scenarios that illustrate the wide range of
 
possible demand for different
energy sources, including fossil fuels, nuclear and renewables. Commodity price sensitivities are presented in a table
 
below and in
note 14 Impairments.
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
71
Equinor assesses climate risk from two perspectives: transition risk, which relates to the financial robustness
 
of the company’s
business model and portfolio in various decarbonisation scenarios; and physical climate risk, which relates
 
to the exposure of our
assets to climate-related perils in different warming scenarios. Equinor’s climate roadmap and all of our
 
climate-related ambitions are
a response to these challenges and risks related to climate change.
●
 
Stricter climate laws, regulations and policies as well as adverse litigation outcomes could adversely
 
impact Equinor's financial
results and outlook, including the value of its assets. This might be directly through regulatory
 
changes towards energy systems
free of unabated fossil fuels, changes in taxation, increased costs, access to opportunities, or indirectly through
 
changes in
consumer behaviour or technology developments.
 
●
 
Changing demand for renewable energy and low-carbon technologies, and innovation and technology
 
changes supporting their
cost-competitive development, represent both threats and opportunities for Equinor. We assess and manage climate-related risks
related to technology development and implementation across our portfolio, as well as recognising
 
risks related to competing or
emerging technologies elsewhere. Examples of relevant technologies within our portfolio include
 
carbon capture and storage
(CCS), blue/green hydrogen, battery technology, solar and wind renewable energy, nuclear fusion, low CO
2
 
intensity solutions,
improvements in methane emissions and application of renewables in oil and gas production.
●
Market development and our ability to reduce costs and capitalize on technology improvements
 
are important but unpredictable
risk factors. Multiple factors in the energy transition contribute to uncertainty in future energy price
 
assumptions, and changes in
investor and societal sentiment can affect our access to capital markets, attractiveness for investors, and potentially
 
restrict
access to finance or increase financing costs.
●
 
Strong competition for assets, changing levels of policy support, and different commercial/contractual models
 
may lead to
diminishing returns within the renewable and low carbon industries and hinder Equinor ambitions.
 
These investments may be
exposed to interest rate risk and inflation risk.
●
 
Changes in physical climate parameters could impact Equinor through increased costs or incidents affecting Equinor’s
operations. Examples of acute physical parameters that could impact Equinor’s facility
 
design and operations include increasing
frequency and severity of extreme weather events such as extreme windspeeds, wave-heights
 
or flooding. Examples of chronic
physical climate parameters include limitations in freshwater availability, a pattern with generally increased wind speeds and as
most of Equinor’s physical assets are located offshore, a key potential chronic physical climate impact is expected
 
to be rising
sea level accompanied with increased wave heights. As we continue to build our renewable
 
portfolio, unexpected changes in
meteorological parameters, such as average wind speed or changes in wind patterns and
 
cloud cover that affect renewable
energy production will also be important factors to consider. Physical risk factors are mitigated through technical and engineering
functions in design, operations and maintenance, with due consideration of how the external
 
physical environment may be
changing. However, there is uncertainty regarding the magnitude of impact and time horizon for the occurrence of physical
impacts of climate change, which leads to uncertainty regarding the potential impact for Equinor.
Impact on Equinor’s financial statements
CO
2
-cost and EU ETS carbon credits
Our oil & gas operations in Europe are part of the EU Emission Trading Scheme (EU ETS). Equinor buys EU
 
ETS allowances (quotas
or carbon credits) for the emissions related to our oil & gas production and processing. Currently
 
we receive a share of free quotas
according to the EU ETS regulation. The share of free quotas is expected to be significantly
 
reduced in the future.
Total expensed CO
2
 
cost related to emissions and purchase of CO
2
quotas in Equinor related to activities resulting in GHG emissions
(Equinor’s share of the operating licences in addition to our land-based facilities)
 
amounts to USD
510
 
million in 2022, USD
428
million in 2021, and USD
268
 
million in 2020. A large portion of the cost of CO
2
 
in Equinor is related to the purchase of EU ETS
quotas. The table below shows an analysis of number of quotas utilised by Equinor’s
 
operated licences and land-based facilities
subject to the requirements under EU ETS:
Number of EU ETS quotas
2022
2021
Opening balance at 1 January
11,026,286
11,027,242
Allocated free quotas
3,697,089
3,560,286
Purchased quotas on the ETS market
5,985,000
7,605,265
Sold quotas on the ETS market
0
(135,177)
Settled quotas (offset against emissions)
(9,925,999)
(11,031,330)
Closing balance at 31 December
10,782,376
11,026,286
 
 
 
 
 
72
 
Equinor, Annual Report on Form 20-F 2022
 
Investments in renewables
The energy transition creates many new business opportunities, primarily related to further
 
development of Equinor’s renewables
business and within CCS. Driven by the energy transition and an increasing demand for
 
electricity from renewable energy sources,
Equinor continues to build its renewable business. We focus on offshore wind and also explore opportunities within onshore
renewables and integrated power market solutions. At present, Equinor’s renewable portfolio
 
spans multiple continents and
technologies– onshore and offshore – and different ownership structures:
●
 
In operation: Mainly offshore wind in UK and Germany and solar farms in Brazil and Argentina
●
 
In construction: The most significant projects are the Dogger Bank projects in UK (SSE
 
operated) and Hywind Tampen in Norway
in addition to construction of solar plants in Poland
●
 
Additional capacity has secured offtake, mainly offshore wind projects in the US and Poland
●
 
Accessed pipeline capacity (currently without offtake). This includes offshore wind in the US and South Korea and
 
solar and
onshore wind projects in Brazil and Poland
●
 
Equinor also holds a
13.1
% shareholding in Scatec ASA, a leading renewable power producer, delivering affordable and clean
energy worldwide
Equinor’s investments in renewables and low carbon solutions projects are included as Additions
 
to PP&E, intangibles and equity
accounted investments in the REN-segment in note 5 Segments and amounts to USD
298
 
million in 2022 and USD
457
 
million in
2021. Equinor's ambition is to become a global offshore wind major and an industry leader in floating
 
offshore wind, drawing on our
extensive offshore experience to drive the industry forward. In addition, Equinor explores opportunities within
 
onshore renewables.
Investments in CCS
Through our activities within CCS, we are building capabilities and a competitive position for future business
 
opportunities and a new
revenue stream related to disposal of CO
2
 
from customers such as from waste incineration and cement production and would also be
basis for solutions for decarbonised hydrogen as an energy carrier which would also be a
 
flexible solution to backup intermittent
renewables in Europe. Equinor is making significant steps to industrialise CCS and we are
 
already involved in the Northern Lights
project in Norway providing CO
2
 
transport and storage solutions (in partnership with Shell and TotalEnergies). It represents the start of
commercial CCS in Europe and is on track to demonstrate that CCS is a valid decarbonisation solution
 
for important industry sectors.
Equinor has during 2022 contributed with USD
36
 
million to the company as capital increases (USD
21
 
million in 2021).
Research and development activities (R&D)
In addition to the beforementioned significant financial effects, Equinor is also involved in several activities within
 
R&D. Several of
these activities are related to optimising our oil and gas activities and cutting emissions from our
 
activities as well as developing new
business opportunities within renewables or low carbon solutions. Financial effects from Equinor’s total
 
R&D activities can be located
in note 9 Auditor’s remuneration and Research and development expenditures
 
(expensed R&D) and in note 12 Property, Plant &
Equipment (capitalised R&D).
Effects on estimation uncertainty
The effects of the initiatives to limit climate changes and the potential impact of the energy transition
 
are relevant to some of the
economic assumptions in our estimations of future cash flows. The results of the development
 
of such initiatives, and the degree to
which Equinor’s operations will be affected by them, are sources of uncertainty. Estimating global energy demand and commodity
prices towards 2050 is a challenging task, as this comprises assessing the future development
 
in supply and demand, technology
change, taxation, tax on emissions, production limits and other important factors. The assumptions
 
may change over time, which
could materialise in different outcomes from the current projected scenarios. This could result in significant changes
 
to accounting
estimates, such as economic useful life (affects depreciation period and timing of asset retirement obligations), value-in-use
calculations (affects impairment assessments) and measurement of deferred tax assets.
Commodity prices
Equinor’s commodity price assumptions applied in value-in-use impairment testing, are
 
set in accordance with requirements in IFRS
and based on management’s best estimate of the development of relevant current circumstances and the likely
 
future development of
such circumstances. This price-set is currently not equal to a price-set required to achieve
 
the goals in the Net Zero Emissions (NZE)
by 2050 Scenario, nor a price-set in accordance with the Announced Pledges Scenario as
 
defined by the International Energy Agency
(IEA). A future change in the trajectory of how the world acts with regards to implementing
 
actions in accordance with the goals in the
Paris agreement could, depending on the detailed characteristics of such a trajectory, have a negative impact on the valuation of
Equinor’s property, plant and equipment in total. A calculation of a possible effect of using the assumed commodity prices and CO
2
prices in a 1.5
o
C compatible NZE by 2050 Scenario as estimated by IEA could result
 
in an impairment of upstream production assets
and intangible assets around USD
4
 
billion before tax, see the sensitivity table below.
Similarly, we have calculated the possible effect of using prices according to the Announced Pledges Scenario, a scenario which is
based on all of the climate-related commitments announced by governments around the Globe.
 
Using this scenario, the world is
expected to reach a 1.8
o
C increase in the year 2100, and this could result in an impairment of less than USD
0.5
 
billion before tax
using the same simplified model, see the sensitivity table below.
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
73
These illustrative impairment sensitivity calculations are based on a simplified model and limitations
 
described in note 14 Impairments.
However, when preparing these illustrative scenario sensitivities, we have linearly interpolated between current prices and the price
set disclosed in the table below for both the NZE by 2050 scenario and the Announced
 
pledges scenario. Applying this simplified
approach, the illustrative potential impairments are significantly lower than the amount disclosed
 
in note 14 Impairments where an
immediate
30
% reduction in commodity prices has been applied, also considering a somewhat declining production
 
profile,
concentrated before the year 2030 for our producing and sanctioned development projects and the
 
effects of discounting.
Cost of CO
2
The EU ETS price has increased significantly from
25
 
EUR/tonne in 2020. The average cost of EU ETS allowances was
81
EUR/tonne in 2022 (
54
 
EUR/tonne in 2021). The price is expected to remain high, in the region
 
of
80
 
EUR/tonne for the next couple of
years. Then the price is expected to be
105
 
EUR/tonne in 2040 and thereafter increasing to
130
 
EUR/tonne in 2050. As such, Equinor
expects greenhouse gas emission costs to increase from current levels and to have a wider geographical
 
range than today, and a
global tax on CO
2
 
emissions will have a negative impact on the valuation of Equinor’s oil and gas
 
assets. Currently, Equinor pays CO
2
fees in Norway, the UK, Germany and Nigeria. Norway’s Climate Action Plan for the period 2021-2030 (Meld. St 13 (2020-2021))
which assumes a gradually increased CO
2
 
tax (the total of EU ETS + Norwegian CO
2
 
tax) in Norway to
2,000
 
NOK/tonne in 2030 is
used for impairment calculations of Norwegian upstream assets.
Equinor’s response to this risk is evaluation of carbon intensity on both project
 
and portfolio level in our investment and divestment
decisions. We have also introduced an internal carbon price, currently set at
58
 
USD/tonne and increasing towards
100
 
USD/tonne by
the year 2030 and staying flat thereafter (in countries with higher carbon costs, we use the
 
country specific cost expectations), to be
used in our investment decisions. This cost-scenario is uncertain, but this extra cost serves
 
as a placeholder for possible future CO
2
pricing systems, making sure our assets are financially robust in such a scenario. As such, climate
 
considerations are a part of the
investment decisions following Equinor’s strategy and commitments to the
 
energy transition.
Climate considerations are also included in the impairment calculations directly by estimating the CO
2
 
taxes in the cash flows.
Indirectly, the expected effect of climate change is included in the estimated commodity prices where supply and demand are
considered. The CO
2
 
prices also have effect on the estimated production profiles and economic cut-off of the projects. Impairment
calculations are based on best estimate assumptions. To reflect that carbon will have a cost for all our assets, the current best
estimate is considered to be EU ETS for countries outside EU where carbon is not already
 
subject to taxation or where Equinor has
not established specific estimates.
Sensitivity table
In this table, we have presented some relevant prices and variables and the anticipated future development
 
compared to our
managements’ best estimate and an illustrative potential impairment effect given these scenarios. The scenario price-sets have
 
been
retrieved from IEA’s report, World Energy Outlook 2022. Prices are adjusted for inflation and presented in Real 2022. USD
2
 
per bbl of
transportation cost has been added to the brent-prices in the scenarios for comparability
 
with our current best estimate
:
Management's price assumptions
1)
NZE by 2050 scenario
Announced Pledged Scenario
Brent blend, 2030
75
USD/bbl
40
USD/bbl
71
USD/bbl
Brent blend, 2040
70
USD/bbl
34
USD/bbl
69
USD/bbl
Brent blend, 2050
65
USD/bbl
28
USD/bbl
67
USD/bbl
TTF, 2030
9.5
USD/MMBtu
5.0
USD/MMBtu
8.5
USD/MMBtu
TTF, 2040
9.0
USD/MMBtu
4.5
USD/MMBtu
7.7
USD/MMBtu
TTF, 2050
9.0
USD/MMBtu
4.1
USD/MMBtu
6.8
USD/MMBtu
EU ETS
2), 3)
, 2030
94
USD/tCO
2
152
USD/tCO
2
146
USD/tCO
2
EU ETS
2), 3)
, 2040
124
USD/tCO
2
222
USD/tCO
2
189
USD/tCO
2
EU ETS
2), 3)
, 2050
153
USD/tCO
2
271
USD/tCO
2
216
USD/tCO
2
Illustrative potential impairment (USD)
~
4.0
billion
<
0.5
billion
1)
Management’s future commodity price assumptions
 
applied when estimating value in use, see note 14
 
Impairments
2)
 
Scenarios: Price of CO
2
 
quotas in advanced economies with net zero pledges,
 
not including any other CO
2
 
taxes
3)
 
EU ETS price assumptions have been translated from EUR
 
to USD using Equinor’s assumptions for currency rates, EUR/USD
 
=
1,176
Robustness of our upstream oil & gas portfolio, and risk of stranded assets
The transition to renewable energy, technological development and the expected reduction in global demand for carbon-based
energy, may have a negative impact on the future profitability of investments in upstream oil and gas assets, in particular assets with
long estimated useful lives, projects in an early development phase and undeveloped assets
 
controlled by Equinor. Equinor uses
scenario analysis to outline different possible energy futures and several of these imply lower oil and natural gas
 
prices. If they
decrease, the oil and gas revenues will also decrease, and potentially reduce the economic
 
lifetime of some assets. Equinor seeks to
mitigate this risk by focusing on improving the resilience of the existing upstream portfolio, maximising
 
the efficiency of our
 
 
74
 
Equinor, Annual Report on Form 20-F 2022
 
infrastructure on the Norwegian Continental Shelf and optimising our high-quality international portfolio. Equinor
 
will continue to add
high value barrels to the portfolio through exploration and increased recovery, and NCS cash flow and value creation are expected to
remain high also beyond 2030. The NCS project portfolio is very robust against potential low
 
oil and gas prices and actions are in
place to both maintain cost discipline across the company and ensure robustness of the non-sanctioned oil
 
and natural gas projects.
Equinor will also continue to selectively explore for new resources with a focus on mature
 
areas with existing infrastructure to minimise
emissions and maximise value. During the transition, Equinor anticipates allocating a smaller share of our
 
capital expenditure to oil
and gas in the coming years and the volume of production is likely to decrease
 
over time. Reaching our
50
 
percent reduction ambition
for operated scope 1 and 2 emissions will require a focused and coordinated effort across the company
 
on executing and maturing
abatement projects, improving energy efficiency of offshore and onshore assets, developing new technologies, and strengthening
resilience in the portfolio. The abatement projects primarily include electrification of offshore assets in Norway, mainly by power from
shore but also including innovations such as Hywind Tampen, our floating wind farm powering offshore oil and gas platforms. In
combination with our focus on renewables and CCS, these abatement projects are expected to reduce Equinor’s
 
emissions
sufficiently to support our mid-term ambitions. As such, Equinor’s plans to become
 
a net-zero company by 2050 have currently not
resulted in the identification of additional assets being triggered for impairment or earlier cessation.
Any future exploration may be restricted by regulations, market and strategic considerations. Provided
 
that the economic assumptions
would deteriorate to such an extent that undeveloped assets controlled by Equinor should not materialize,
 
assets at risk mainly
comprise the intangible assets Oil and Gas prospects, signature bonuses and the capitalised
 
exploration costs, with a total carrying
value of USD
3,634
 
million. See note 13 Intangible assets for more information regarding Equinor’s
 
intangible assets.
Timing of Asset Retirement Obligations (ARO)
As mentioned above, there are currently no assets triggered for earlier cessation as a result
 
of Equinor’s plans to become a net-zero
company by 2050. But, if the business cases of Equinor’s oil and gas
 
producing assets in the future should change materially due to
governmental initiatives to limit climate change, this could affect the timing of cessation of our assets and
 
also our asset retirement
obligations. A shorter production period, accelerating the time for when assets need to be removed
 
after ended production, will
increase the carrying value of the liability. To
 
illustrate the potential financial effect of earlier removal, we have estimated the effect of
performing removal five years earlier than currently scheduled to an increase in the liability of
 
around USD
1
 
billion. See note 23
Provisions and other liabilities for more information regarding Equinor’s ARO.
4 Financial risk and capital management
General information and financial risks
Equinor's business activities naturally expose Equinor to financial risks such as market risk (including
 
commodity price risk, currency
risk, interest rate risk and equity price risk), liquidity risk and credit risk. Equinor’s approach
 
to risk management includes assessing
and managing risk in activities using a holistic risk approach, by considering relevant correlations at portfolio
 
level between the most
important market risks and the natural hedges inherent in Equinor’s portfolio. This
 
approach allows Equinor to reduce the number of
risk management transactions and avoid sub-optimisation.
The corporate risk committee, which is headed by the chief financial officer, is responsible for Equinor’s Enterprise Risk Management
and for proposing appropriate measures to adjust risk at the corporate level. This includes assessing
 
Equinor’s financial risk policies.
Market risk
Equinor operates in the worldwide crude oil, refined products, natural gas, and electricity markets
 
and is exposed to market risks
including fluctuations in hydrocarbon prices, foreign currency rates, interest rates, and electricity
 
prices that can affect the revenues
and costs of operating, investing, and financing. These risks are managed primarily on a short-term basis with
 
a focus on achieving
the highest risk-adjusted returns for Equinor within the given mandate. Long-term exposures
 
are managed at the corporate level,
while short-term exposures are managed according to trading strategies and mandates. Mandates in
 
the trading organisations within
crude oil, refined products, natural gas,
 
and electricity are relatively restricted compared to the total market risk of Equinor.
Commodity price risk
Equinor’s most important long-term commodity risk (crude oil and natural gas)
 
is related to future market prices as Equinor´s risk
policy is to be exposed to both upside and downside price movements. In the longer term, also
 
power price risk is to a large extent
expected to contribute to Equinor’s commodity price risk portfolio.
To manage short-term commodity risk, Equinor enters into
commodity-based derivative contracts, including futures,
 
options, over-the-counter (OTC) forward contracts, market swaps and
contracts for differences related to crude oil, petroleum products, natural gas, power and emissions. Equinor’s
 
bilateral gas sales
portfolio is exposed to various price indices with a combination of gas price markers.
The term of crude oil and refined oil products derivatives are usually less than one year, and they are traded mainly on the Inter-
Continental Exchange (ICE) in London, the New York Mercantile Exchange (NYMEX), the OTC Brent market, and crude and refined
products swap markets. The term of natural gas, power, and emission derivatives is usually three years or less, and they are mainly
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
75
OTC physical forwards and options, NASDAQ OMX Oslo forwards, and futures traded on the European
 
Energy Exchange (EEX),
NYMEX and ICE.
The table below contains the commodity price risk sensitivities of Equinor's commodity-based derivative
 
contracts. Equinor's assets
and liabilities resulting from commodity-based derivative contracts consist of both exchange traded and non-exchange
 
traded
instruments, including embedded derivatives that have been bifurcated and recognised at fair value in the
 
Consolidated balance
sheet.
Price risk sensitivities at the end of 2022 and 2021 at
30
% are assumed to represent a reasonably possible change based on the
duration of the derivatives. Since none of the derivative financial instruments included in the
 
table below are part of hedging
relationships, any changes in the fair value would be recognised in the Consolidated statement
 
of income.
Commodity price sensitivity
At 31 December
2022
2021
(in USD million)
- 30%
+ 30%
- 30%
+ 30%
Crude oil and refined products net gains/(losses)
666
(666)
735
(735)
Natural gas, electricity and CO2 net gains/(losses)
(3)
140
227
(141)
Currency risk
Equinor’s cash flows from operating activities deriving from oil and gas sales,
 
operating expenses and capital expenditures are mainly
in USD, but taxes, dividends to shareholders on the Oslo Børs and a share of our operating
 
expenses and capital expenditures are in
NOK. Accordingly, Equinor’s currency management is primarily linked to mitigate currency risk related to payments in NOK. This
means that Equinor regularly purchases NOK, primarily spot, but also on a forward basis
 
using conventional derivative instruments.
The following currency risk sensitivity for financial instruments has been calculated, by assuming
 
a
12
% reasonable possible change
in the most relevant foreign currency exchange rates that impact Equinor’s
 
financial accounts, based on balances at 31 December
2022. As of 31 December 2021, a change of
10
% in the most relevant foreign currency exchange rates was viewed
 
as a reasonable
possible change. With reference to the table below, an increase in the foreign currency exchange rates means that the disclosed
currency has strengthened in value against all other currencies. The estimated gains and the
 
estimated losses following from a
change in the foreign currency exchange rates would impact the Consolidated statement of income.
Currency risk sensitivity
At 31 December
2022
2021
(in USD million)
- 12 %
+ 12%
- 10 %
+ 10%
USD net gains/(losses)
(1,497)
1,497
(1,789)
1,789
NOK net gains/(losses)
1,583
(1,583)
2,144
(2,144)
Interest rate risk
Bonds are normally issued at fixed rates in a variety of currencies (among others USD, EUR
 
and GBP) and some of these bonds are
converted to floating USD bonds by using interest rate and currency swaps. Equinor manages its
 
interest rates exposure on its bond
portfolio based on risk and reward considerations from an enterprise risk management perspective. This means
 
that the fixed/floating
mix on interest rate exposure may vary from time to time. For more detailed information
 
about Equinor’s long-term debt portfolio see
note 21 Finance debt.
The following interest rate risk sensitivity has been calculated by assuming a change of
1.2
 
percentage points as a reasonable
possible change in interest rates at the end of 2022. In 2021, a change of
0.8
 
percentage points in interest rates was viewed as a
reasonable possible change. A decrease in interest rates will have an estimated positive impact
 
on net financial items in the
Consolidated statement of income, while an increase in interest rates will have an estimated negative
 
impact on net financial items in
the Consolidated statement of income.
Interest risk sensitivity
At 31 December
2022
2021
(in USD million)
 
- 1.2 percentage
points
+ 1.2 percentage
points
 
- 0.8 percentage
points
+ 0.8 percentage
points
Positive/(negative) impact on net financial items
369
(366)
448
(448)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
76
 
Equinor, Annual Report on Form 20-F 2022
 
Equity price risk
Equinor’s captive insurance company holds listed equity securities as part of its portfolio.
 
In addition, Equinor holds some other listed
and non-listed equities mainly for long-term strategic purposes. By holding these assets, Equinor
 
is exposed to equity price risk,
defined as the risk of declining equity prices, which can result in a decline in the carrying
 
value of certain Equinor’s assets recognised
in the balance sheet. The equity price risk in the portfolio held by Equinor’s captive insurance
 
company is managed, with the aim of
maintaining a moderate risk profile, through geographical diversification and the use of broad
 
benchmark indexes.
The following equity price risk sensitivity has been calculated, by assuming a
35
% reasonable possible change in equity prices that
impact Equinor’s financial accounts, based on balances at 31 December 2022. At 31 December
 
2021, a change of
35
% in equity
prices was equally viewed as a reasonable possible change. The estimated gains and the
 
estimated losses following from a change in
equity prices would impact the Consolidated statement of income.
Equity price sensitivity
At 31 December
2022
2021
(in USD million)
- 35%
+ 35%
- 35%
+ 35%
Net gains/(losses)
(450)
450
(534)
534
Liquidity risk
Liquidity risk is the risk that Equinor will not be able to meet obligations of financial
 
liabilities when they become due. The purpose of
liquidity management is to ensure that Equinor always has sufficient funds available to cover its financial obligations.
The main cash outflows include the quarterly dividend payments and Norwegian petroleum tax
 
payments made six times per year.
Trading in collateralised commodities and financial contracts also exposes Equinor to liquidity risk related to potential collateral calls
from counterparties.
 
If the cash flow forecasts indicate that the liquid assets will fall below target levels,
 
new long-term funding will be considered. Equinor
raises debt in all major capital markets (USA, Europe and Asia) for long-term funding purposes.
 
The policy is to have a maturity profile
with repayments not exceeding
5
% of capital employed in any year for the nearest five years. Equinor’s
 
non-current financial liabilities
have a weighted average maturity of approximately nine years. For more information about
 
Equinor’s non-current financial liabilities,
see note 21 Finance debt.
Short-term funding needs will normally be covered by the USD
5.0
 
billion US Commercial paper programme (CP) which is backed by
a revolving credit facility of USD
6.0
 
billion, supported by
19
 
core banks,
maturing in 2025
. The facility supports secure access to
funding, supported by the best available short-term rating. As at 31 December 2022 the facility
 
has not been drawn upon.
The table below shows a maturity profile, based on undiscounted contractual cash flows, for Equinor’s
 
financial liabilities.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
77
At 31 December
2022
2021
(in USD million)
Non-derivative financial
liabilities
Lease
liabilities
Derivative
financial
liabilities
Non-derivative financial
liabilities
Lease
liabilities
Derivative
financial
liabilities
Year 1
20,172
1,325
1,065
18,841
1,183
175
Year 2 and 3
6,292
1,421
752
6,684
1,262
211
Year 4 and 5
 
5,785
504
486
6,140
656
318
Year 6 to 10
8,749
465
1,202
10,636
642
588
After 10 years
11,204
120
706
12,849
158
187
Total specified
52,202
3,835
4,211
55,150
3,901
1,479
Credit risk
Credit risk is the risk that Equinor’s customers or counterparties will cause Equinor financial
 
loss by failing to honour their obligations.
Credit risk arises from credit exposures with customer accounts receivables as well as from financial investments,
 
derivative financial
instruments and deposits with financial institutions. Equinor uses risk mitigation tools to reduce
 
or control credit risk both on a
counterparty and portfolio level. The main tools include bank and parental guarantees, prepayments,
 
and cash collateral.
Prior to entering into transactions with new counterparties, Equinor’s credit policy requires all counterparties to be formally identified
and assigned internal credit ratings. The internal credit ratings reflect Equinor’s assessment of the counterparties' credit risk and are
based on a quantitative and qualitative analysis of recent financial statements and other relevant business information. All
counterparties are re-assessed regularly.
Equinor has
 
pre-defined limits
 
for the
 
absolute credit
 
risk level
 
allowed at
 
any given
 
time on
 
Equinor’s portfolio
 
as well
 
as maximum
credit exposures for individual counterparties. Equinor monitors the portfolio on
 
a regular basis and individual exposures against limits
on a daily basis.
 
Equinor’s total credit
 
exposure is geographically
 
diversified among a
 
number of counterparties within
 
the oil and
 
energy
sector, as well
 
as larger
 
oil and
 
gas consumers
 
and financial
 
counterparties. The
 
majority of
 
Equinor’s credit
 
exposure is
 
with investment-
grade counterparties.
The following table contains the carrying amount of Equinor’s financial receivables
 
and derivative financial instruments split by
Equinor’s assessment of the counterparty's credit risk. Trade and other receivables include
1
% overdue receivables of more than 30
days. A provision has been recognised for expected credit losses of trade and other receivables
 
using the expected credit loss model.
Only non-exchange traded instruments are included in derivative financial instruments.
(in USD million)
Non-current
financial
receivables
Trade and other
receivables
Non-current
derivative
financial
instruments
Current derivative
financial
instruments
At 31 December 2022
Investment grade, rated A or above
1,633
6,125
390
1,715
Other investment grade
12
8,725
41
1,393
Non-investment grade or not rated
14
6,761
259
931
Total financial assets
1,659
21,611
690
4,039
At 31 December 2021
Investment grade, rated A or above
452
3,637
1,103
2,902
Other investment grade
18
8,930
0
1,524
Non-investment grade or not rated
238
4,624
162
705
Total financial assets
708
17,191
1,265
5,131
For more information about Trade and other receivables, see note 18 Trade and other receivables.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
78
 
Equinor, Annual Report on Form 20-F 2022
 
The table below presents the amounts offset under the terms of various master netting agreements for financial assets and liabilities.
Amounts not qualifying for offsetting consists of collateral receipts or payments which usually is settled on a gross
 
basis. Normally
these amounts will offset in a potential default situation. There exist no restrictions on collaterals received.
(in USD million)
Gross amounts of
recognised
financial assets/
liabilities
Gross amounts
offset in the
balance sheet
Net amounts
presented in the
balance sheet
Amounts of
remaining rights
to set-off not
qualifying for
offsetting
Net amount
At 31 December 2022
Financial assets
Trade receivables
25,607
7,464
18,143
0
18,143
Collateral receivables
19,043
15,575
3,468
3,468
0
Derivative financial instruments
30,078
25,348
4,730
1,708
3,022
Total financial assets
74,728
48,387
26,341
5,176
21,165
Financial liabilities
Trade payables
19,913
7,464
12,449
0
12,449
Collateral liabilities
15,479
13,907
1,572
1,571
1
Derivative financial instruments
33,497
27,015
6,482
3,605
2,877
Total financial liabilities
68,889
48,386
20,503
5,176
15,327
(in USD million)
Gross amounts of
recognised
financial assets/
liabilities
1)
Gross amounts
offset in the
balance sheet
1)
Net amounts
presented in the
balance sheet
Amounts of
remaining rights
to set-off not
qualifying for
offsetting
Net amount
At 31 December 2021
Financial assets
Trade receivables
20,061
4,445
15,616
0
15,616
Collateral receivables
1)
9,902
8,327
1,576
1,576
0
Derivative financial instruments
1)
32,493
26,097
6,396
2,771
3,625
0
Total financial assets
1)
62,456
38,869
23,588
4,347
19,241
0
Financial liabilities
0
Trade payables
16,795
4,445
12,350
0
12,350
Collateral liabilities
1)
9,851
7,580
2,271
2,271
0
Derivative financial instruments
1)
32,218
26,844
5,375
2,076
3,299
Total financial liabilities
1)
58,864
38,869
19,996
4,347
15,649
1) Gross amounts have been restated due to reassessment of certain exchange traded derivatives
 
and related collaterals previously
not recognised on the Consolidated balance sheet, with no effect on net amounts presented.
Capital management
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
79
The main objectives of Equinor's capital management policy are to maintain a strong overall financial
 
position and to ensure sufficient
financial flexibility. Equinor’s primary focus is on maintaining its credit rating in the A category on a stand alone basis (excluding uplifts
for Norwegian Government ownership). Equinor’s current long-term ratings are AA- with
 
a stable outlook (including one notch uplift)
and Aa2 with a stable outlook (including two notch uplift) from S&P
 
and Moody’s, respectively. In order to monitor financial robustness,
a key ratio utilised by Equinor is the non-GAAP metric of “Net interest-bearing debt adjusted (ND)
 
to Capital employed adjusted*
(CE)”.
At 31 December
(in USD million)
2022
2021
Net interest-bearing debt adjusted, including lease
 
liabilities (ND1)
(6,750)
3,236
Net interest-bearing debt adjusted (ND2)
(10,417)
(326)
Capital employed adjusted, including lease liabilities
 
(CE1)
47,239
42,259
Capital employed adjusted (CE2)
43,571
38,697
Net debt to capital employed adjusted*, including lease
 
liabilities (ND1/CE1)
(14.3%)
7.7%
Net debt to capital employed adjusted* (ND2/CE2)
(23.9%)
(0.8%)
ND1 is defined as Equinor's interest-bearing financial liabilities less cash and cash equivalents and current
 
financial investments,
adjusted for collateral deposits and balances held by Equinor's captive insurance company (amounting to USD
6,538
 
million and USD
2,369
 
million for 2022 and 2021, respectively). CE1 is defined as Equinor's total equity (including
 
non-controlling interests) and ND1.
ND2 is defined as ND1 adjusted for lease liabilities (amounting to USD
3,668
 
million and USD
3,562
 
million for 2022 and 2021,
respectively). CE2 is defined as Equinor's total equity (including non-controlling interests) and ND2.
5 Segments
Accounting policies
Equinor’s operations are managed through operating segments identified on the
 
basis of those components of Equinor that are
regularly reviewed by the chief operating decision maker, Equinor's corporate executive committee (CEC). The reportable segments
Exploration & Production Norway (E&P Norway), Exploration & Production International (E&P
 
International), Exploration & Production
USA (E&P USA), Marketing, Midstream & Processing (MMP) and Renewables
 
(REN) correspond to the operating segments. The
operating segments Projects, Drilling & Procurement (PDP), Technology, Digital & Innovation (TDI) and Corporate staff and functions
are aggregated into the reportable segment Other based on materiality. The majority of the costs in PDP and TDI is allocated to the
three Exploration & Production segments, MMP and REN.
The accounting policies of the reporting segments equal those described in these Consolidated
 
financial statements, except for the
line-item Additions to PP&E, intangibles and equity accounted investments in which movements
 
related to changes in asset retirement
obligations are excluded as well as provisions for onerous contracts which reflect only obligations
 
towards group external parties. The
measurement basis of segment profit is net operating income/(loss). Deferred tax assets, pension
 
assets, non-current financial assets,
total current assets and total liabilities are not allocated to the segments. Transactions between the segments, mainly from the
 
sale of
crude oil, gas,
 
and related products, are performed at defined internal prices which have been derived from market
 
prices. The
transactions are eliminated upon consolidation.
With effect from 2022, Equinor changed the measurement basis for the segments related to leases. Up to
 
and including 2021, all
leases were presented within the Other segment and lease costs were allocated to the
 
operating segments based on underlying lease
payments with a corresponding credit in the Other segment. With effect from 2022, lease contracts are
 
accounted for in accordance
with IFRS 16 Leases in all segments. This change does not affect Equinor’s Consolidated financial
 
statements except the segment
disclosures in this note. Comparative numbers in the segments have been restated.
----------------------------------------------------------------------------------------------------------------------------------------
The Exploration & Production operating segments are responsible for the discovery and appraisal
 
of new resources, commercial
development and safe and efficient operation of the oil and gas portfolios within their respective geographical
 
areas: E&P Norway on
the Norwegian continental shelf, E&P USA in USA and E&P International worldwide
 
outside of E&P Norway and E&P USA.
PDP is responsible for global project development, well deliveries, and sourcing across Equinor.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
80
 
Equinor, Annual Report on Form 20-F 2022
 
TDI encompasses research, technology development, specialist advisory services, digitalisation, IT, improvement, innovation, and
ventures and future business.
MMP is responsible for the marketing, trading, processing and transportation of crude oil and condensate,
 
natural gas, NGL and
refined products, and includes refinery, terminals, and processing plant operation. MMP is also managing power and emissions trading
and the development of transportation solutions for natural gas, liquids, and crude oil, including pipelines,
 
shipping, trucking and rail. In
addition, MMP is in charge of low carbon solutions in Equinor.
REN is developing, exploring, investing in, and operating areas within renewable energy such as
 
offshore wind, green hydrogen,
storage solutions, and solar power.
Segment information for the years ended 31 December 2022, 2021, and 2020 are presented below. For revenues per geographical
area, please see note 7 Total revenues and other income. For further information on the following items affecting the segments,
please refer to the related notes: note 6 Acquisitions and disposals, note 14 Impairments, and note 26 Other
 
commitments, contingent
liabilities, and contingent assets.
2022
E&P
Norway
 
E&P
International
E&P USA
MMP
REN
Other
Eliminations
 
Total
 
(in USD million)
Revenues third party, other revenue and
other income
1,299
1,134
305
147,173
127
149
0
150,186
Revenues inter-segment
74,631
6,124
5,217
527
0
55
(86,554)
0
Net income/(loss) from equity accounted
investments
0
172
0
406
58
(16)
0
620
Total revenues and other income
 
75,930
7,431
5,523
148,105
185
187
(86,554)
150,806
Purchases [net of inventory variation]
0
(116)
0
(139,916)
0
0
86,227
(53,806)
Operating, selling, general and
administrative expenses
(3,782)
(1,698)
(938)
(4,591)
(265)
(223)
904
(10,595)
Depreciation and amortisation
(4,986)
(1,445)
(1,422)
(881)
(4)
(142)
0
(8,878)
Net impairment (losses)/reversals
819
(286)
1,060
895
0
0
0
2,487
Exploration expenses
(366)
(638)
(201)
0
0
0
0
(1,205)
Total operating expenses
(8,315)
(4,183)
(1,501)
(144,493)
(269)
(365)
87,131
(71,995)
Net operating income/(loss)
67,614
3,248
4,022
3,612
(84)
(178)
577
78,811
Additions to PP&E, intangibles and equity
accounted investments
4,922
2,623
764
1,212
298
176
0
9,994
Balance sheet information
Equity accounted investments
 
3
550
0
688
1,452
65
0
2,758
Non-current segment assets
 
28,510
15,868
11,311
4,619
316
1,031
0
61,656
Non-current assets not allocated to
segments
 
15,437
Total non-current assets
 
79,851
Assets classified as held for sale
0
1,018
0
0
0
0
0
1,018
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
81
2021
E&P
Norway
1)
E&P
International
1)
E&P
 
USA
1)
MMP
1)
REN
1)
Other
1)
Eliminations
1
)
Total
(in USD million)
Revenues third party, other revenue and
other income
1)
414
1,121
377
87,050
1,394
307
0
90,665
Revenues inter-segment
1)
38,972
4,230
3,771
321
0
41
(47,335)
0
Net income/(loss) from equity accounted
investments
0
214
0
22
16
7
0
259
Total revenues and other income
1)
39,386
5,566
4,149
87,393
1,411
355
(47,335)
90,924
Purchases [net of inventory variation]
0
(58)
0
(80,873)
0
(1)
45,772
(35,160)
Operating, selling, general and
administrative expenses
1)
(3,653)
(1,405)
(1,074)
(3,753)
(163)
(432)
1,102
(9,378)
Depreciation and amortisation
1)
(6,002)
(1,734)
(1,665)
(869)
(3)
(158)
0
(10,432)
Net impairment (losses)/reversals
1)
1,102
(1,587)
(69)
(735)
0
2
0
(1,287)
Exploration expenses
(363)
(451)
(190)
0
0
0
0
(1,004)
Total operating expenses
1)
(8,915)
(5,237)
(2,998)
(86,230)
(166)
(590)
46,873
(57,261)
Net operating income/(loss)
1)
30,471
329
1,150
1,163
1,245
(234)
(461)
33,663
Additions to PP&E, intangibles and equity
accounted investments
1)
4,943
1,834
690
517
457
64
0
8,506
Balance sheet information
Equity accounted investments
 
3
1,417
0
113
1,108
45
0
2,686
Non-current segment assets
1)
36,502
15,422
11,406
4,006
157
1,032
0
68,527
Non-current assets not allocated to
segments
 
13,406
Total non-current assets
 
84,618
Assets classified as held for sale
0
676
0
0
0
0
0
676
1)
Restated due to implementation of IFRS 16 in the
 
segments, mainly affecting the line items Operating, selling,
 
general and administrative
expenses in MMP (reduction of USD
523
 
million), E&P Norway (reduction of USD
77
 
million) and Other (increase of USD
696
 
million),
Depreciation and amortisation in MMP (increase of USD
509
 
million), E&P Norway (increase of USD
222
 
million) and Other (reduction of
USD
799
 
million) and Non-current segment assets in
 
MMP (increase of USD
987
 
million), E&P Norway (increase of USD
1,201
 
million)
and Other (decrease of USD
2,255
 
million).
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
82
 
Equinor, Annual Report on Form 20-F 2022
 
2020
E&P
Norway
1)
E&P
International
1)
E&P
 
USA
MMP
1)
REN
1)
Other
1)
Eliminations
Total
(in USD million)
Revenues third party, other revenue and
other income
1)
215
452
368
44,623
18
88
0
45,765
Revenues inter-segment
11,804
3,183
2,247
309
0
39
(17,581)
0
Net income/(loss) from equity accounted
investments
0
(146)
0
31
163
5
0
53
Total revenues and other income
1)
12,019
3,489
2,615
44,963
181
132
(17,581)
45,818
Purchases [net of inventory variation]
0
(72)
0
(38,072)
0
1
17,157
(20,986)
Operating, selling, general and
administrative expenses
1)
(2,736)
(1,374)
(1,310)
(4,564)
(214)
(59)
722
(9,537)
Depreciation and amortisation
1)
(4,466)
(2,105)
(1,889)
(875)
(1)
(178)
(1)
(9,515)
Net impairment (losses)/reversals
1)
(1,260)
(1,426)
(1,938)
(1,076)
0
(19)
(1)
(5,720)
Exploration expenses
(423)
(2,071)
(990)
0
0
1
(1)
(3,483)
Total operating expenses
1)
(8,886)
(7,048)
(6,127)
(44,587)
(216)
(254)
17,877
(49,241)
Net operating income/(loss)
1)
3,133
(3,559)
(3,512)
376
(35)
(122)
295
(3,423)
Additions to PP&E, intangibles and equity
accounted investments
1)
5,004
2,588
1,067
1,048
33
22
0
9,762
Balance sheet information
Equity accounted investments
3
1,125
0
95
1,017
25
0
2,262
Non-current segment assets
1)
39,355
17,960
12,588
5,605
4
1,144
0
76,657
Non-current assets not allocated to
segments
13,704
Total non-current assets
92,623
Assets classified as held for sale
0
0
1,159
0
203
0
0
1,362
1)
Restated due to implementation of IFRS 16 in the
 
segments, mainly affecting the line items Operating, selling,
 
general and administrative
expenses in MMP (reduction of USD
494
 
million), E&P Norway (reduction of USD
93
 
million) and Other (increase of USD
693
 
million),
Depreciation and amortisation in MMP (increase of USD
481
 
million), E&P Norway (increase of USD
181
 
million) and Other (reduction of
USD
718
 
million) and Non-current segment assets in
 
MMP (increase of USD
1,238
 
million), E&P Norway (increase of USD
1,623
 
million)
and Other (decrease of USD
2,987
 
million).
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
83
Non-current assets by country
At 31 December
(in USD million)
2022
2021
Norway
33,242
40,564
USA
12,343
12,323
Brazil
9,400
8,751
UK
3,688
2,096
Azerbaijan
1,401
1,654
Canada
1,171
1,403
Angola
895
948
Algeria
622
708
Argentina
615
474
Denmark
497
536
Other
541
1,757
Total non-current assets
1)
64,414
71,213
1)
Excluding deferred tax assets, pension assets and non-current
 
financial assets.
 
Equinor’s non-current assets in Norway have decreased by USD
7,322
 
million to USD
33,242
 
million at 31 December 2022 compared
to year-end 2021, mainly due to increased discount rates and strengthening of USD versus NOK.
 
The decrease has mainly affected
Property, plant and equipment,
 
see note 12.
 
 
84
 
Equinor, Annual Report on Form 20-F 2022
 
6 Acquisitions and disposals
Accounting policies
Business combinations
Business combinations, except for transactions between entities under common control, are accounted for
 
using the acquisition
method. The purchase price includes total consideration paid to acquire the entity’s assets and liabilities, as well
 
as contingent
consideration at fair value. The acquired identifiable assets, liabilities and contingent liabilities are
 
measured at fair value at the date of
the acquisition. Acquisition costs incurred are expensed under Selling, general and administrative
 
expenses. Changes in the fair value
of contingent consideration resulting from events after the acquisition date are recognised in
 
the Consolidated statement of income
under Other income.
Equinor recognises a gain/loss on disposal of a subsidiary when control is lost. Any remaining
 
interest in the former subsidiary is
recognised at fair value. When partially divesting subsidiaries which do not constitute a business, and where
 
the remaining investment
in the former subsidiary is an associate or a jointly controlled investment, Equinor only recognises
 
the gain or loss on the divested part
within Other income or Operating expenses, respectively. The remaining interest in the former subsidiary is initially not remeasured,
and subsequently accounted for using the equity method.
After-tax disposals
On the NCS, all disposals of assets are performed including the tax base (after-tax). Any gain
 
includes the release of tax liabilities
previously recognised related to the assets in question and is recognised in full in Other income in
 
the Consolidated statement of
income.
Assets classified as held for sale
Non-current assets are classified separately as held for sale in the Consolidated balance sheet when
 
a sale is highly probable. This
condition is met when an asset is available for immediate sale in its present condition,
 
Equinor’s management is committed to the
sale, and the sale is expected to be completed within one year from the date
 
of classification. In Equinor, these requirements are
normally met when management has approved a negotiated letter of intent with the
 
counterparties (a ‘DGC’). Liabilities directly
associated with the assets classified as held for sale and expected to be included as part of the
 
sales transaction, are also classified
separately. The net assets and liabilities of a disposal group classified as held for sale are measured at the lower of their carrying
amount and fair value less costs to sell.
Accounting judgement regarding acquisitions
Determining whether an acquisition meets the definition of a business combination requires judgement to
 
be applied on a case-by-
case basis. Acquisitions are assessed to establish whether the transaction represents a business
 
combination or an asset purchase,
and the conclusion may materially affect the financial statements both in the transaction period and subsequent
 
periods. Similar
assessments are performed upon the acquisition of an interest in a joint operation. Depending
 
on the specific facts, acquisitions of
exploration and evaluation licences for which a development decision has not yet been made have
 
largely been concluded to
represent asset purchases, while purchases of producing assets have largely been concluded to
 
represent business acquisitions.
Accounting judgement regarding partial divestments
The policy regarding partial divestments of subsidiaries is based on careful consideration of the
 
requirements and scope of IFRS 10
Consolidated Financial Statements and IAS 28 Investments in Associates and Joint Ventures. The conclusion requires judgement to
be applied on a case-by-case basis, considering the substance of the transactions. In evaluating
 
the standards’ requirements, Equinor
acknowledges pending considerations related to several relevant and similar issues which have
 
been postponed by the IASB in
anticipation of concurrent consideration at a later date. Where assets are transferred into separate legal
 
entities concurrently with a
portion of the entities’ shares being sold to a third party, thereby resulting in Equinor’s loss of control of those asset-owning
subsidiaries, and where investments in joint ventures are established simultaneously, Equinor has concluded to only recognise the
gain on the divested portion.
----------------------------------------------------------------------------------------------------------------------------------------
2022
Acquisitions
Acquisition of BeGreen
On 26 January 2023, Equinor closed a transaction with the Bregentved Group
 
and members of the executive board of BeGreen Solar
Aps to acquire
100
% of BeGreen Solar Aps for a cash consideration of USD
277
 
million (EUR
260
 
million) and a consideration
contingent on successful delivery of future solar projects above an agreed MW threshold. BeGreen
 
Solar Aps is a Danish solar
developer. At closing, USD
226
 
million (EUR
213
 
million) of the cash consideration was paid and recognised in the REN
 
segment.
Acquisition of Triton Power
Equinor, Annual Report on Form 20-F 2022
 
85
On 1 September 2022, Equinor and SSE Thermal Generation Holdings Limited (SSE
 
Thermal) closed a transaction to acquire the UK
power company Triton Power Holdings Ltd (Triton Power) from Triton Power Partners LP owned by Energy Capital Partners (ECP).
Equinor’s share of the consideration was USD
141
 
million (GBP
120
 
million), after adjustments that mainly related to net debt and
working capital. The key plant included in the purchase of Triton Power is the Saltend Power Station with an installed
 
capacity of
1.2
GW. Equinor and SSE Thermal own
50
% each of Triton Power, and Equinor is accounting for the investment under the equity method
as a joint venture in the MMP segment.
Acquisition of Statfjord licence shares
On 31 May 2022, Equinor closed a transaction to acquire all of Spirit Energy’s interests in
 
production licences in the Statfjord area
which covers the Norwegian and UK Continental Shelves and consists of three integrated
 
production platforms and satellite subsea
installations. All licences are operated by Equinor. Spirit Energy’s ownership shares in the licences covered by the transaction range
from
11.56
% to
48.78
%. The cash consideration received was USD
193
 
million, whereof USD
25
 
million related to Spirit’s lifting of
volumes on Equinor’s behalf in June 2022. The assets and liabilities acquired have
 
been reflected in accordance with the principles in
IFRS 3 Business Combinations. The transaction is reflected in the E&P Norway and E&P
 
International segments with a cash
consideration of USD
96
 
million and USD
72
 
million, respectively.
In the segment E&P Norway, the acquisition resulted in an increase of USD
98
 
million in property, plant and equipment, an increase of
USD
390
 
million in asset retirement obligation, a reduction of deferred tax liability of USD
298
 
million and an increase in taxes payable
of USD
98
 
million. In the segment E&P International, the acquisition resulted in an increase of USD
98
 
million in property, plant and
equipment, an increase of USD
241
 
million in asset retirement obligation and an increase of deferred tax asset of USD
86
 
million.
Disposals
Ekofisk and Martin Linge on the Norwegian Continental Shelf
On 30 September 2022, Equinor closed a transaction with Sval Energi AS to divest Equinor’s
 
entire ownership share in the Greater
Ekofisk Area including its share in Norpipe Oil AS, and a
19
% ownership share in Martin Linge. The cash consideration paid upon
closing of the transaction amounted to USD
293
 
million after interim period settlement. In addition, an estimated contingent
consideration of USD
169
 
million linked to realised oil and gas prices for 2022 and 2023 was recognised. Equinor
 
retained a
51
%
ownership share in Martin Linge and continues as operator of the field. The disposal
 
resulted in a decrease in property, plant and
equipment of USD
1,493
 
million, a decrease in asset retirement obligation of USD
376
 
million, a decrease in deferred tax liability of
USD
597
 
million and a decrease in taxes payable of USD
686
 
million. A post-tax gain of USD
655
 
million is presented in the line item
Other income in the Consolidated statement of income in the E&P Norway segment.
Exit Russia
Following Russia’s invasion of Ukraine in February 2022, Equinor announced that it had decided to stop new investments
 
in Russia
and start the process of exiting Equinor’s joint arrangements. Based on this
 
decision, Equinor evaluated its assets in Russia and
recognised net impairments of USD
1,083
 
million in the first quarter, of which USD
251
 
million was related to property, plant and
equipment and intangible assets and USD
832
 
million was related to investments accounted for using the equity method. The
impairments were net of contingent consideration from the time of acquiring the assets. The impairments
 
were recognised in the line
items Depreciation, amortisation and net impairment losses and Exploration expenses in the Consolidated statement
 
of income based
on the nature of the impaired assets and reflected in the E&P International segment. During
 
the second quarter, Equinor transferred
its participating interests in four Russian entities to Rosneft and was released from all future
 
commitments and obligations with no
material impact on the financial statements. The ownership interests in Kharyaga were transferred
 
to the operator.
Equinor has stopped trading in Russian oil. This means that Equinor will not enter into any new
 
trades or engage in new transport of
oil and oil products from Russia. Equinor has assessed the accounting impact of certain commitments
 
arising from such contracts
entered into prior to the invasion and deem the impact to be immaterial.
10% of Dogger Bank C
On 10 February 2022, Equinor closed the transaction with Eni to sell a
10
% equity interest in the Dogger Bank C project in the UK for
a total consideration of USD
91
 
million (GBP
68
 
million), resulting in a gain of USD
87
 
million (GBP
65
 
million). After closing, Equinor’s
ownership share is
40
%. Equinor continues to equity account for the remaining investment as a joint
 
venture. The gain is presented in
the line item Other income in the Consolidated statement of income in the REN segment.
Held for sale
Equinor Energy Ireland Limited
In the fourth quarter of 2021, Equinor entered into an agreement with Vermilion Energy Inc (Vermilion) to sell Equinor’s non-operated
equity position in the Corrib gas project in Ireland. The transaction covers a sale of
100
% of the shares in Equinor Energy Ireland
Limited (EEIL). EEIL owns
36.5
% of the Corrib field alongside the operator Vermilion (
20
%) and Nephin Energy (
43.5
%). Equinor and
86
 
Equinor, Annual Report on Form 20-F 2022
 
Vermilion have agreed a consideration of USD
434
 
million before closing adjustments and contingent consideration linked to 2022
production level and gas prices. Closing is dependent on governmental approval and is expected
 
to take place during the first quarter
2023.
2021
Acquisitions
Wento
On 5 May 2021, Equinor completed a transaction to acquire
100
% of the shares in Polish onshore renewables developer Wento from
the private equity firm Enterprise Investors for a cash consideration of USD
117
 
million (EUR
98
 
million) after net cash adjustments.
The assets and liabilities related to the acquired business were recognised under the acquisition method. The
 
acquisition resulted in
an increase of Equinor’s intangible assets of USD
46
 
million and goodwill of USD
59
 
million. The goodwill reflects the expected
synergies, competence and access to the Polish renewables market obtained in the acquisition.
 
The transaction has been accounted
for in the REN segment.
Disposals
Equinor Refining Denmark A/S
On 31 December 2021, Equinor Danmark A/S closed the transaction with the Klesch Group to sell
100
% of the shares in Equinor
Refining Denmark A/S (ERD). Klesch paid USD
48
 
million of the total estimated consideration at closing. ERD consists of
the Kalundborg refinery and associated terminals and infrastructure. Following an impairment earlier
 
in 2021, the disposal resulted in
an immaterial loss. Prior to transaction closing, Equinor received USD
335
 
million in extraordinary dividend and repayment of paid-
in capital from ERD.
 
Following the disposal, a gain of USD
167
 
million was recycled from Other comprehensive income (OCI) to the Consolidated
statement of income in the line item Other income and has been reflected in the MMP segment.
Terra Nova
On 8 September 2021, Equinor closed the transaction with Cenovus and Murphy to
 
sell
100
% of its interest, which includes a release
of any future obligations and liabilities, in the Terra Nova asset in offshore Canada. The transaction was accounted for in the E&P
International segment. The consideration paid, the net carrying amount and the impact to the Consolidated
 
statement of income are
immaterial.
Bakken onshore unconventional field
On 26 April 2021, Equinor closed the transaction to divest its interests in the Bakken
 
field in the US states of North Dakota and
Montana to Grayson Mill Energy, backed by EnCap Investments for an estimated total consideration of USD
819
 
million, including
interim period settlement, for which payment was received in the first half of 2021. The asset had
 
been impaired in 2021 prior to
closing. Subsequent to closing, insignificant losses were recorded and are presented in the line item Operating
 
expenses in the
Consolidated statement of income in the E&P USA segment.
10% of Dogger Bank Farm A and B
On 26 February 2021, Equinor closed the transaction with Eni to sell a
10
% equity interest in the Dogger Bank Wind Farm A and B
assets in the UK for a total consideration of USD
285
 
million (GBP
206
 
million), resulting in a gain of USD
280
 
million (GBP
203
million). After closing, Equinor has a
40
% shareholding in Dogger Bank A and Dogger Bank B, and will continue to equity
 
account for
the remaining investment as a joint venture. The gain is presented in the line item Other
 
income in the Consolidated statement of
income in the REN segment.
Non-operated interest in the Empire Wind and Beacon Wind assets on the US east coast
On 29 January 2021, Equinor closed the transaction with BP to sell
50
% of the non-operated interests in the Empire Wind and Beacon
Wind assets for a preliminary total consideration after interim period adjustments of USD
1.2
 
billion, resulting in a gain of USD
1.1
billion for the divested part, of which USD
500
 
million had been prepaid at the end of December 2020. Through this transaction, the
two companies have established a strategic partnership for further growth within offshore wind in the
 
USA. Following the transaction,
Equinor remains the operator with a
50
% interest. Equinor consolidated the assets until transaction closing,
 
and thereafter the
investments are classified as joint ventures and accounted for using the equity method. The gain is
 
presented in the line item Other
income in the Consolidated statement of income in the REN segment.
7 Total
 
revenues and other income
Accounting policies
Revenue recognition
Equinor presents Revenue from contracts with customers and Other revenue as a single caption,
 
Revenues, in the Consolidated
statement of income.
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
87
Revenue from contracts with customers
Revenue from the sale of crude oil, natural gas, petroleum products and other merchandise is recognised
 
when a customer obtains
control of those products, which normally is when title passes at point of delivery, based on the contractual terms of the agreements.
Each such sale normally represents a single performance obligation. In the case of natural gas,
 
which is delivered on a continuous
basis through pipelines, sales are completed over time in line with the delivery of the actual physical quantities.
Sales and purchases of physical commodities are presented on a gross basis as Revenues from contracts
 
with customers and
Purchases [net of inventory variation] respectively in the Consolidated statement of income. When
 
the contracts are deemed financial
instruments or part of Equinor’s trading activities, they are settled and presented
 
on a net basis as Other revenue. Reference is made
to note 28 Financial instruments and fair value measurement for a description of accounting policies
 
regarding derivatives. Sales of
Equinor’s own produced oil and gas volumes are always reflected gross as Revenue
 
from contracts with customers.
Revenues from the production of oil and gas in which Equinor shares an interest with other
 
companies are recognised on the basis of
volumes lifted and sold to customers during the period (the sales method). Where Equinor
 
has lifted and sold more than the
ownership interest, an accrual is recognised for the cost of the overlift. Where Equinor has lifted and sold less
 
than the ownership
interest, costs are deferred for the underlift.
Other revenue
Items representing a form of revenue, or which are related to revenue from contracts with customers,
 
are presented as Other revenue
if they do not qualify as revenue from contracts with customers. These other revenue
 
items include taxes paid in-kind under certain
production sharing agreements (PSAs) and the net impact of commodity trading and commodity-based derivative
 
instruments related
to sales contracts or revenue-related risk management.
Transactions with the Norwegian State
Equinor markets and sells the Norwegian State's share of oil and gas production from the
 
Norwegian continental shelf (NCS). The
Norwegian State's participation in petroleum activities is organised through the SDFI (the Norwegian State’s Direct
 
Financial
Interests). All purchases and sales of the SDFI's oil production are classified as purchases [net of
 
inventory variation] and revenues
from contracts with customers, respectively.
Equinor sells, in its own name, but for the SDFI’s account and risk, the SDFI’s production of natural gas. These gas sales
 
and related
expenditures refunded by the SDFI are presented net in the Consolidated financial statements. Natural gas
 
sales made in the name of
Equinor’s subsidiaries are also presented net of the SDFI’s share in the Consolidated statement of income,
 
but this activity is reflected
gross in the Consolidated balance sheet.
Accounting judgement related to transactions with the Norwegian State
Whether to account for the transactions gross or net involves the use of significant accounting
 
judgement. In making the judgement,
Equinor has considered whether it controls the State-originated crude oil volumes prior to onwards
 
sales to third party customers.
Equinor directs the use of the volumes, and although certain benefits from the sales subsequently
 
flow to the SDFI, Equinor
purchases the crude oil volumes from the SDFI and obtains substantially all the remaining benefits. On
 
that basis, Equinor has
concluded that it acts as principal in these sales.
Regarding gas sales, Equinor concluded that ownership of the gas had not been transferred from
 
the SDFI to Equinor. Although
Equinor has been granted the ability to direct the use of the volumes, all the benefits from the sales
 
of these volumes flow to the SDFI.
On that basis, Equinor is not considered the principal in the sale of the SDFI’s natural gas volumes.
Reference is made to note 27 Related parties for detailed financial information regarding transactions
 
performed between Equinor and
SDFI.
----------------------------------------------------------------------------------------------------------------------------------------
Revenues from contracts with customers by geographical areas
Equinor has business operations in around 30
 
countries.
When attributing the line-item Revenues from contracts with customers for 2022
to the country of the legal entity executing the sale for 2022, Norway constitutes
84
% and USA constitutes
13
%. For 2021 the
revenues to Norway and USA constituted
81
% and
13
% respectively, and for 2020
80
% and
14
% respectively.
Revenues from contracts with customers and
 
other revenues
(in USD million)
Note
2022
2021
2020
Crude oil
58,524
38,307
24,509
Natural gas
65,232
28,050
7,213
 
 
 
 
 
 
88
 
Equinor, Annual Report on Form 20-F 2022
 
 
- European gas
58,239
24,900
5,839
 
- North American gas
2,884
1,783
1,010
 
- Other incl LNG
4,109
1,368
363
Refined products
11,093
11,473
6,534
Natural gas liquids
9,240
8,490
5,069
Transportation
1,470
921
1,083
Other sales
4,702
1,006
681
Total revenues from contracts with customers
150,262
88,247
45,088
Taxes paid in-kind
412
345
93
Physically settled commodity derivatives
(2,534)
(1,075)
209
Gain/(loss) on commodity derivatives
739
951
108
Change in fair value of trading inventory
(194)
0
0
Other revenues
319
276
256
Total other revenues
(1,258)
497
665
Revenues
149,004
88,744
45,753
Net income/(loss) from equity accounted investments
15
620
259
53
Other income
6
1,182
1,921
12
Total revenues and other income
150,806
90,924
45,818
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
89
8 Salaries and personnel expenses
 
(in USD million, except average number of employees)
2022
2021
2020
Salaries
1)
2,875
2,962
2,625
Pension costs
2)
458
488
432
Payroll tax
433
414
368
Other compensations and social costs
324
288
283
Total payroll expenses
4,090
4,152
3,707
Average number of employees
3)
21,500
21,400
21,700
1)
Salaries include bonuses, severance packages and expatriate costs in addition to base pay.
2)
 
See note 22 Pensions.
3)
 
Part time employees amount to
3
% for 2022 and 2021 and
2
% for 2020.
Total payroll expenses are accumulated in cost-pools and partially charged to partners of Equinor operated licences on an hours
incurred basis.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
90
 
Equinor, Annual Report on Form 20-F 2022
 
Compensation to the board of directors (BoD) and the corporate executive committee (CEC)
(in USD million)
1)
2022
2021
2020
Current employee benefits
12.9
12.2
9.0
Post-employment benefits
0.4
0.4
0.6
Other non-current benefits
0.0
0.0
0.0
Share-based payment benefits
0.2
0.1
0.1
Total benefits
13.5
12.7
9.7
1) All figures in the table are presented on accrual basis.
At 31 December 2022, 2021, and 2020 there are
no
 
loans to the members of the BoD or the CEC.
Share-based compensation
Equinor's share saving plan provides employees with the opportunity to purchase Equinor shares through
 
monthly salary deductions
and a contribution by Equinor. If the shares are kept for two full calendar years of continued employment following the year of
purchase, the employees will be allocated one bonus share for each share they have purchased.
Estimated compensation expense including the contribution by Equinor for purchased shares, amounts
 
vested for bonus shares
granted and related social security tax was USD
85
 
million, USD
79
 
million, and USD
74
 
million related to the 2022, 2021 and 2020
programmes, respectively. For the 2023 programme (granted in 2022), the estimated compensation expense is USD
78
 
million. At 31
December 2022 the amount of compensation cost yet to be expensed throughout the vesting period is
 
USD
174
 
million.
See note 20 Shareholders’ equity and dividends for more information about share-based compensation.
9 Auditor’s remuneration and Research and development expenditures
 
Auditor's remuneration
Full year
(in USD million, excluding VAT)
2022
2021
2020
Audit fee
11.4
14.4
10.7
Audit related fee
 
1.8
1.1
1.0
Tax fee
-
-
-
Other service fee
 
-
-
-
Total remuneration
13.2
15.5
11.7
In addition to the figures in the table above, the audit fees and audit related fees related to Equinor
 
operated licences amount to USD
0.6
 
million, USD
0.5
 
million and USD
0.5
 
million for 2022, 2021 and 2020, respectively.
Research and development expenditures (R&D)
Equinor has R&D activities within exploration, subsurface, drilling and well, facilities, low carbon
 
and renewables. R&D activities
contribute to maximising and developing long-term value from Equinor’s assets. R&D
 
expenditures are partially financed by partners
of Equinor operated licences.
R&D expenditures including amounts charged to partners were USD
308
 
million, USD
291
 
million and USD
254
 
million in 2022, 2021
and 2020, respectively. Equinor's share of the expenditures has been recognised within Total operating expenses in the Consolidated
statement of income.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
91
10 Financial items
Full year
(in USD million)
2022
2021
2020
Foreign currency exchange gains/(losses) derivative
 
financial instruments
 
797
870
(1,288)
Other foreign currency exchange gains/(losses)
1,291
(823)
642
Net foreign currency exchange gains/(losses)
2,088
47
(646)
Dividends received
93
39
44
Interest income financial investments, including
 
cash and cash equivalents
398
38
108
Interest income non-current financial receivables
30
26
34
Interest income other current financial assets and other
 
financial items
701
48
113
Interest income and other financial items
1,222
151
298
Gains/(losses) financial investments
(394)
(348)
456
Gains/(losses) other derivative financial instruments
(1,745)
(708)
448
Interest expense bonds and bank loans and net
 
interest on related derivatives
(1,029)
(896)
(951)
Interest expense lease liabilities
(90)
(93)
(104)
Capitalised borrowing costs
382
334
308
Accretion expense asset retirement obligations
(449)
(453)
(412)
Interest expense current financial liabilities and
 
other finance expense
(192)
(114)
(232)
Interest expenses and other finance expenses
(1,379)
(1,223)
(1,392)
Net financial items
(207)
(2,080)
(836)
Equinor's main financial items relate to assets and liabilities categorised in the fair value through
 
profit or loss and the amortised cost
categories. For more information about financial instruments by category see note 28 Financial instruments
 
and fair value
measurement.
Foreign currency exchange gains/(losses) derivative financial instruments include fair value changes of currency
 
derivatives related to
liquidity and currency risk. The line item Other foreign currency exchange gains/(losses) includes
 
a fair value loss from derivatives
related to non-current debt of USD
691
 
million in 2022, a loss of USD
702
 
million in 2021 and a gain of USD
796
 
million in 2020.
The line item Gains/(losses) other derivative financial instruments primarily includes fair value changes from interest
 
rate related
derivatives, with a loss of USD
1,760
 
million and USD
724
 
million in 2022 and 2021 respectively, and a gain of USD
432
 
million in
2020.
The line item Interest expense bonds and bank loans and net interest on related derivatives
 
includes interest expenses of USD
918
million, USD
990
 
million, and USD
1,031
 
million for 2022, 2021 and 2020, respectively, from the financial liabilities at amortised cost
category. It also includes net interest on related derivatives from the fair value through profit or loss category, amounting to a net
interest expense of USD
111
million for 2022, net interest income of USD
94
 
million and USD
79
 
million for 2021 and 2020,
respectively.
 
92
 
Equinor, Annual Report on Form 20-F 2022
 
11 Income
 
taxes
Accounting policies
 
Income tax
Income tax in the Consolidated statement of income comprises current and deferred tax expense.
 
Income tax is recognised in the
Consolidated statement of income except when it relates to items recognised in OCI.
Current tax consists of the expected tax payable on the taxable income for the year and any
 
adjustment to tax payable for previous
years. Uncertain tax positions and potential tax exposures are analysed individually. The outcomes of tax disputes are mostly binary
in nature, and in each case the most likely amount for probable liabilities to be paid (including
 
penalties) or assets to be received
(disputed tax positions for which payment has already been made) is recognised within Current tax
 
or Deferred tax as appropriate.
Uplift benefit on the NCS is recognised when the deduction is included in the
 
current year tax return and impacts taxes payable.
Deferred tax assets and liabilities are recognised for the future tax consequences attributable to
 
differences between the carrying
amounts of existing assets and liabilities and their respective tax bases, and on unused tax losses
 
and credits carried forward, subject
to the initial recognition exemption. A deferred tax asset is recognised only to the extent that it
 
is probable that future taxable income
will be available against which the asset can be utilised. For a deferred tax asset to be recognised
 
based on future taxable income,
convincing evidence is required, considering the existence of contracts, production of oil or gas in the
 
near future based on volumes of
expected reserves, observable prices in active markets, expected volatility of trading profits,
 
expected foreign currency rate
movements and similar facts and circumstances.
When an asset retirement obligation or a lease contract is initially reflected in the accounts, a deferred
 
tax liability and a corresponding
deferred tax asset are recognised simultaneously and accounted for in line with other deferred tax
 
items. The applied policy is in line
with an amendment to IAS 12 Income Taxes, reducing the scope of the initial recognition exemption, which is effective from 1 January
2023.
Estimation uncertainty regarding income tax
Equinor incurs significant amounts of income taxes payable to various jurisdictions and may
 
recognise significant changes to deferred
tax assets and deferred tax liabilities. There may be uncertainties related to interpretations
 
of applicable tax laws and regulations
regarding amounts in Equinor’s tax returns, which are filed in a number
 
of tax regimes. For cases of uncertain tax treatments, it may
take several years to complete the discussions with relevant tax authorities or to reach resolutions
 
of the appropriate tax positions
through litigation.
The carrying values of income tax related assets and liabilities are based on Equinor's interpretations
 
of applicable laws, regulations
and relevant court decisions. The quality of these estimates, including the most likely outcomes
 
of uncertain tax treatments, is
dependent upon proper application of at times very complex sets of rules, the recognition of
 
changes in applicable rules and, in the
case of deferred tax assets, management's ability to project future earnings from activities that may apply loss carry
 
forward positions
against future income taxes. Climate-related matters and the transition to carbon-neutral
 
energy-consumption globally have increased
the uncertainty in determining key business assumptions used to assess the recoverability of
 
deferred tax assets through sufficient
future taxable income before tax losses expire.
-----------------------------------------------------------------------------------------------------------------------------------
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
93
Significant components of income tax expense
Full year
(in USD million)
2022
2021
2020
Current income tax expense in respect of
 
current year
(52,124)
(21,271)
(1,115)
Prior period adjustments
(112)
(28)
313
Current income tax expense
(52,236)
(21,299)
(802)
Origination and reversal of temporary differences
(2,136)
(1,778)
(648)
Recognition of previously unrecognised deferred
 
tax assets
4,401
126
130
Change in tax regulations
0
4
(12)
Prior period adjustments
110
(60)
94
Deferred tax income/(expense)
2,375
(1,708)
(435)
Income tax
(49,861)
(23,007)
(1,237)
Changes to tax regimes
Norway
As a measure to maintain activity in the oil and gas related industry during the Covid-19
 
pandemic, the Norwegian Government
enacted temporary targeted changes to Norway’s petroleum tax system for investments incurred in 2020 and 2021, and for new
projects with Plan for development and operations (PDOs) or Plan for installation and
 
operations (PIOs) submitted to the Ministry of
Oil and Energy by the end of 2022 and approved prior to 1 January 2024. The changes were effective from
 
1 January 2020 and
provided companies with a direct tax deduction in the special petroleum tax instead of
 
tax depreciation over six years. In addition, the
tax uplift benefit, was recognised over one year instead of four years. Tax depreciation towards the ordinary offshore corporate tax
was continued
 
with a six-year depreciation profile.
 
On 17 June 2022, the Norwegian Parliament adopted amendments to the Petroleum Tax Act to convert the special tax for petroleum
activities to a cash flow tax. The amendments were effective 1 January 2022 and maintains the marginal
 
rate for special petroleum tax
and corporate income tax at
56
% and
22
% respectively but allows for cost of investments in the year of investment and
 
calculated
corporate income tax to be deducted in the special petroleum tax base. Uplift deductions for
 
investments incurred after 1 January
2022 was discontinued. The uplift deduction rate under the temporary rules was reduced to
17.69
% for 2022 and further reduced to
12.4
% as from 2023.
 
UK
On 23 May 2022, the UK introduced a new levy intended to tax windfall profits on oil and gas production
 
from the United Kingdom
Continental Shelf, called the Energy (Oil & Gas) Profits Levy Act 2022 (EPL).
EPL was introduced as a new temporary tax at the rate of
25
% from 26 May 2022 to 31 December 2022, and further increased to
35
% from 1 January 2023 to 31 March 2028. It applies to profits on transactions from
 
that date forward with no tax relief for prior
expenditures or brought forward losses and with no EPL tax relief
 
for interest and decommissioning costs. Capital cost incurred since
26 May 2022 are eligible for an EPL deductible uplift of
80
% until 31 December 2022 and thereafter at
29
% for expenditure other than
that in respect of de-carbonisation where the rate of uplift remains at
80
%. EPL losses can be carried forward without limitation and
carried back for one year.
 
US
On August 16, 2022, the Inflation Reduction Act (IRA) was enacted in the USA. As
 
from 2023, under the IRA a Corporate Minimum
Tax on Book Earnings (BMT) applies a
15
% tax on adjusted financial statement income. The enactment of the IRA had no
 
impact in
2022.
 
 
 
 
 
 
 
 
 
 
 
 
 
94
 
Equinor, Annual Report on Form 20-F 2022
 
Reconciliation of statutory tax rate to effective
 
tax rate
Full year
(in USD million)
2022
2021
2020
Income/(loss) before tax
78,604
31,583
(4,259)
Calculated income tax at statutory rate
1)
(18,168)
(7,053)
1,445
Calculated Norwegian Petroleum tax
2)
(36,952)
(17,619)
(2,126)
Tax effect uplift
3)
259
914
1,006
Tax effect of permanent differences regarding divestments
417
90
(9)
Tax effect of permanent differences caused by functional currency different from tax currency
145
150
(198)
Tax effect of other permanent differences
403
228
450
Recognition of previously unrecognised deferred tax
 
assets
4)
4,401
126
130
Change in unrecognised deferred tax assets
(34)
619
(1,685)
Change in tax regulations
0
4
(12)
Prior period adjustments
(3)
(88)
408
Other items including foreign currency effects
(327)
(378)
(647)
Income tax
(49,861)
(23,007)
(1,237)
Effective tax rate
63.4 %
72.8 %
(29.0 %)
1)
The weighted average of statutory tax rates was
23.1
% in 2022,
22.3
% in 2021 and
33.9
% in 2020. The rates are influenced by
earnings composition between tax regimes with lower statutory tax rates and tax regimes with higher statutory
 
tax rates.
2)
 
The Norwegian petroleum income is taxable at a tax rate of
71.8
% after deduction for
22
% corporate tax in the special petroleum
tax basis.
3)
 
When calculating the petroleum tax of
71.8
% on income from the Norwegian continental shelf, an additional tax-free allowance
(uplift) was previously granted on the basis of the original capitalised cost of offshore production installations.
Previously, a
5.2
% uplift could be deducted from taxable income for a period of four years starting
 
when the capital expenditure
was incurred. On 17 June 2022, the Norwegian Parliament adopted amendments to the Petroleum
 
Tax Act and converted the
special tax for petroleum activities to a cash flow tax. The amendments were effective 1 January 2022. Uplift
 
deductions for
investments incurred after 1 January 2022 were discontinued. At year-end 2022, un-recognised uplift credits were
zero
,
compared to USD
272
 
million at year-end 2021.
For 2020 and 2021, temporary rules enacted under the Covid-19 pandemic allowed direct deduction of the whole
 
uplift at a rate
of
24
% in the year the capital expenditure was incurred. This rate was reduced
 
to
17.69
% for 2022, and further reduced to
12.4
%
on capital expenditures incurred on investments eligible under the temporary rules as from 2023.
4)
 
An amount of USD
4,401
 
million of previously un-recognised deferred tax assets was recognised in 2022, resulting in
 
a lower
effective tax rate for 2022 compared to 2021. More than
90
% of the recognition relates to the US, that after a history of significant
losses, is now recording profits. Projected future taxable income demonstrates that it is probable that the
 
unused tax losses
carried forward can be utilised in the nearest future. The tax value of unused accumulated losses
 
recognised as a deferred tax
asset in the US, amounts to USD
2,738
 
million at year-end 2022.
A
30
% decline in commodity prices, considered to represent a
reasonably possible change, would have an immaterial impact on the recognised amount.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
95
Deferred tax assets and liabilities comprise
(in USD million)
Tax losses
carried
forward
Property,
plant and
equipment
 
and
intangible
assets
Asset
retirement
obligations
Lease
liabilities
Pensions
Derivatives
Other
Total
Deferred tax assets
8,105
694
7,356
1,306
694
1,131
1,348
20,634
Deferred tax liabilities
(28)
(23,356)
0
(3)
(12)
(3)
(411)
(23,813)
Net asset/(liability) at 31 December
2022
8,077
(22,662)
7,356
1,303
682
1,128
937
(3,179)
Deferred tax assets
5,162
719
11,256
1,506
804
21
2,015
21,484
Deferred tax liabilities
0
(27,136)
0
0
(21)
(1,453)
(530)
(29,140)
Net asset/(liability) at 31 December
2021
5,162
(26,417)
11,256
1,506
783
(1,432)
1,485
(7,655)
Changes in net deferred tax liability during
 
the year were as follows:
(in USD million)
2022
2021
2020
Net deferred tax liability at 1 January
7,655
6,250
5,530
Charged/(credited) to the Consolidated statement of income
(2,375)
1,708
435
Charged/(credited) to Other comprehensive income
105
35
(19)
Acquisitions and disposals
(968)
36
0
Foreign currency translation effects and other effects
(1,239)
(374)
304
Net deferred tax liability at 31 December
3,179
7,655
6,250
 
 
 
 
 
 
 
 
 
96
 
Equinor, Annual Report on Form 20-F 2022
 
Deferred tax assets and liabilities are offset to the extent that the deferred taxes relate to the same fiscal
 
authority, and there is a
legally enforceable right to offset current tax assets against current tax liabilities. After netting deferred tax assets
 
and liabilities by
fiscal entity and reclassification to Assets held for sale, deferred taxes are presented on the Consolidated
 
balance sheet as follows:
At 31 December
(in USD million)
2022
2021
Deferred tax assets
8,732
6,259
Deferred tax liabilities
11,996
14,037
Deferred tax assets reported in Assets classified as
 
held for sale
85
122
Deferred tax assets are recognised based on the expectation that sufficient taxable income will be available
 
through reversal of
taxable temporary differences or future taxable income. At year-end 2022, the deferred tax assets of USD
8,817
 
million were primarily
recognised in the US, the UK, Norway, Angola, Canada and Brazil. Of this amount, USD
1,953
 
million was recognised in entities
which have suffered a tax loss in either the current or the preceding period. The corresponding amounts for 2021, were
 
USD
6,381
million and USD
4,636
 
million, respectively. The tax losses will be utilised through reversal of taxable temporary differences and future
taxable income, mainly from production of oil and gas.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
97
Unrecognised deferred tax assets
At 31 December
2022
2021
(in USD million)
Basis
Tax
Basis
Tax
Deductible temporary differences
2,558
968
2,900
1,203
Unused tax credits
0
129
0
264
Tax losses carried forward
3,458
930
20,552
5,047
Total unrecognised deferred tax assets
6,016
2,027
23,452
6,514
Approximately
90
% of the unrecognised carry forward tax losses can be carried forward indefinitely. The majority of the unrecognised
tax losses that cannot be carried forward indefinitely expire
after 2027
. The unrecognised tax credits expire from 2030, while the
unrecognised deductible temporary differences do not expire under the current tax legislation. Deferred tax assets
 
have not been
recognised in respect of these items because currently there is insufficient evidence to support that future taxable
 
profits will be
available to secure utilisation of the benefits.
At year-end 2022, unrecognised deferred tax assets in Angola and Canada represents USD
636
 
million and USD
346
 
million,
respectively, of the total unrecognised deferred tax assets of USD
2,027
 
million. Similar amounts for 2021 were USD
4,206
 
million in
the USA and USD
749
 
million in Angola, respectively, of a total of USD
6,514
 
million. The remaining unrecognised deferred tax assets
originate from several different tax jurisdictions.
 
 
98
 
Equinor, Annual Report on Form 20-F 2022
 
12 Property,
 
plant and equipment
Accounting policies
Property, plant and equipment
Property, plant and equipment is reflected at cost, less accumulated depreciation and impairment. The initial cost of an asset
comprises its purchase price or construction cost, any costs directly attributable to bringing the asset into operation,
 
the initial estimate
of an asset retirement obligation, exploration costs transferred from intangible assets and, for
 
qualifying assets, borrowing costs.
Proceeds from production ahead of a project’s final approval are regarded as ‘early production’ and is
 
recognised as revenue rather
than as a reduction of acquisition cost. Contingent consideration included in the acquisition
 
of an asset or group of similar assets is
initially measured at its fair value, with later changes in fair value other than due
 
to the passage of time reflected in the book value of
the asset or group of assets, unless the asset is impaired. Property, plant and equipment include costs relating to expenditures
incurred under the terms of production sharing agreements (PSAs) in certain countries, and which qualify for
 
recognition as assets of
Equinor. State-owned entities in the respective countries, however, normally hold the legal title to such PSA-based property, plant and
equipment.
Expenditure on major maintenance refits or repairs comprises the cost of replacement assets
 
or parts of assets, inspection costs and
overhaul costs. Inspection and overhaul costs, associated with regularly scheduled major maintenance
 
programmes planned and
carried out at recurring intervals exceeding one year, are capitalised and amortised over the period to the next scheduled inspection
and overhaul. All other maintenance costs are expensed as incurred.
Capitalised exploration and evaluation expenditures, development expenditure on the construction,
 
installation or completion of
infrastructure facilities such as platforms, pipelines and the drilling of production wells, and field-dedicated transport
 
systems for oil
and gas are capitalised as Producing oil and gas properties within Property, plant and equipment. Such capitalised costs, when
designed for significantly larger volumes than the reserves from already developed and producing
 
wells, are depreciated using the
unit of production method (UoP) based on proved reserves expected to be recovered from the
 
area during the concession or contract
period. Depreciation of production wells uses the UoP method based on proved developed reserves,
 
and capitalised acquisition costs
of proved properties are depreciated using the UoP method based on total proved reserves. In the
 
rare circumstances where the use
of proved reserves fails to provide an appropriate basis reflecting the pattern in which the
 
asset’s future economic benefits are
expected to be consumed, a more appropriate reserve estimate is used. Depreciation of other assets
 
and transport systems used by
several fields is calculated on the basis of their estimated useful lives, normally using the straight-line method.
 
Each part of an item of
property, plant and equipment with a cost that is significant in relation to the total cost of the item is depreciated separately. For
exploration and production assets, Equinor has established separate depreciation categories which
 
as a minimum distinguish
between platforms, pipelines and wells.
The estimated useful lives of property, plant and equipment are reviewed on an annual basis, and changes in useful lives are
accounted for prospectively. An item of property, plant and equipment is derecognised upon disposal. Any gain or loss arising on
derecognition of the asset is included in Other income or Operating expenses, respectively, in the period the item is derecognised.
Monetary or non-monetary grants from governments, when related to property, plant and equipment and considered reasonably
certain, are recognised in the Consolidated balance sheet as a deduction to the carrying
 
value of the asset and subsequently
recognised in the Consolidated statement of income over the life of the depreciable asset
 
as a reduced depreciation expense.
Research and development
Equinor undertakes research and development both on a funded basis for licence holders and on
 
an unfunded basis for projects at its
own risk, developing innovative technologies to create opportunities and enhance the value of current
 
and future assets. Expenses
relate both to in-house resources and the use of suppliers. Equinor's own share of the licence
 
holders' funding and the total costs of
the unfunded projects are considered for capitalisation under the applicable IFRS
 
requirements. Subsequent to initial recognition, any
capitalised development costs are accounted for in the same manner as Property, plant and equipment. Costs not qualifying for
capitalisation are expensed as incurred, see note 9 Auditor’s remuneration
 
and Research and development expenditures for more
details.
Estimation uncertainty regarding determining oil and gas reserves
Reserves quantities are, by definition, discovered, remaining, recoverable and economic. Recoverable oil and
 
gas quantities are
always uncertain. Estimating reserves is complex and based on a high degree of professional judgement
 
involving geological and
engineering assessments of in-place hydrocarbon volumes, the production, historical recovery and processing
 
yield factors and
installed plant operating capacity. The reliability of these estimates depends on both the quality and availability of the technical and
economic data and the efficiency of extracting and processing the hydrocarbons.
Estimation uncertainty; Proved oil and gas reserves
Proved oil and gas reserves may impact the carrying amounts of oil and gas producing
 
assets, as changes in the proved reserves, will
impact the unit of production rates used for depreciation and amortisation. Proved oil and gas
 
reserves are those quantities of oil and
gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable
 
certainty to be economically producible
 
Equinor, Annual Report on Form 20-F 2022
 
99
from a given date forward, from known reservoirs, and under existing economic conditions, operating
 
methods, and government
regulations. Unless evidence indicates that renewal is reasonably certain, estimates of proved reserves
 
only reflect the period before
the contracts providing the right to operate expire. For future development projects, proved reserves
 
estimates are included only
where there is a significant commitment to project funding and execution and when relevant governmental
 
and regulatory approvals
have been secured or are reasonably certain to be secured.
Proved reserves are divided into proved developed and proved undeveloped reserves. Proved developed
 
reserves are to be
recovered through existing wells with existing equipment and operating methods, or where the
 
cost of the required equipment is
relatively minor compared to the cost of a new well. Proved undeveloped reserves are to
 
be recovered from new wells on undrilled
acreage, or from existing wells where a relatively major capital expenditure is required. Undrilled
 
well locations can be classified as
having proved undeveloped reserves if a development plan is in place indicating that they are scheduled
 
to be drilled within five years
unless specific circumstances justify a longer time horizon. Specific circumstances are for instance fields which
 
have large up-front
investments in offshore infrastructure, such as many fields on the NCS, where drilling of wells is scheduled
 
to continue for much
longer than five years. For unconventional reservoirs where continued drilling of new wells is a major part of the
 
investments, such as
the US onshore assets, the proved reserves are always limited to proved well locations
 
scheduled to be drilled within five years.
Proved oil and gas reserves have been estimated by internal qualified professionals based on industry
 
standards and are governed by
the oil and gas rules and disclosure requirements in the U.S. Securities and Exchange Commission
 
(SEC) regulations S-K and S-X,
and the Financial Accounting Standards Board (FASB) requirements for supplemental oil and gas disclosures. The estimates have
been based on a 12-month average product price and on existing economic conditions and operating
 
methods as required, and
recovery of the estimated quantities have a high degree of certainty (at least a 90% probability).
 
An independent third party has
evaluated Equinor's proved reserves estimates, and the results of this evaluation do not differ materially from Equinor's
 
estimates.
Estimation uncertainty; Expected oil and gas reserves
Changes in the expected oil and gas reserves may materially impact the amounts of asset
 
retirement obligations, as a consequence
of timing of the removal activities. It will also impact value-in-use calculations for oil and gas assets,
 
possibly affecting impairment
testing and the recognition of deferred tax assets. Expected oil and gas reserves are the estimated
 
remaining, commercially
recoverable quantities, based on Equinor's judgement of future economic conditions, from projects in
 
operation or decided for
development. As per Equinor’s internal guidelines, expected reserves are defined
 
as the ‘forward looking mean reserves’ when based
on a stochastic prediction approach. In some cases, a deterministic prediction method is used, in which
 
case the expected reserves
are the deterministic base case or best estimate. Expected reserves are therefore typically larger
 
than proved reserves as defined by
the SEC, which are high confidence estimates with at least a 90% probability of recovery
 
when a probabilistic approach is used.
Expected oil and gas reserves have been estimated by internal qualified professionals based on industry
 
standards and classified in
accordance with the Norwegian resource classification system issued by the Norwegian Petroleum
 
Directorate.
-----------------------------------------------------------------------------------------------------------------------------
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
100
 
Equinor, Annual Report on Form 20-F 2022
 
(in USD million)
Machinery,
equipment and
transportation
equipment
Production
plants and oil
and gas
assets
Refining and
manufacturing
plants
Buildings
and land
Assets under
development
Right of use
assets
4)
Total
Cost at 1 January 2022
1,335
183,358
8,481
596
12,614
5,850
212,234
Additions and transfers
6)
52
9,390
378
6
(813)
1,319
10,332
Changes in asset retirement obligations
0
(4,756)
0
0
(48)
0
(4,805)
Disposals at cost
(9)
(3,487)
2
(20)
(5)
(347)
(3,865)
Foreign currency translation effects
(36)
(12,557)
(576)
(19)
(934)
(188)
(14,310)
Cost at 31 December 2022
1,343
171,948
8,285
562
10,815
6,633
199,586
Accumulated depreciation and impairment
losses at 1 January 2022
(1,188)
(137,763)
(7,926)
(320)
(344)
(2,619)
(150,159)
Depreciation
(52)
(7,643)
(160)
(33)
0
(969)
(8,856)
Impairment losses
(8)
(187)
(39)
0
(49)
(4)
(286)
Reversal of impairment losses
4
2,585
802
0
207
0
3,599
Transfers
6)
(2)
(20)
2
0
20
(8)
(8)
Accumulated depreciation and impairment
on disposed assets
8
2,002
(4)
5
0
347
2,359
Foreign currency translation effects
34
9,571
562
9
30
59
10,264
Accumulated depreciation and impairment
losses at 31 December 2022
5)
(1,203)
(131,455)
(6,763)
(338)
(135)
(3,194)
(143,088)
Carrying amount at 31 December 2022
140
40,493
1,522
224
10,679
3,439
56,498
Estimated useful lives (years)
 
3 - 20
UoP
1)
 
15 - 20
 
10 - 33
2)
 
1 - 20
3)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
101
(in USD million)
Machinery,
equipment and
transportation
equipment
Production
plants and oil
and gas
assets
Refining and
manufacturing
plants
Buildings
and land
Assets under
development
Right of use
assets
Total
Cost at 1 January 2021
2,806
183,082
9,238
929
13,163
6,370
215,587
Additions and transfers
6)
39
9,439
95
27
(355)
148
9,393
Changes in asset retirement obligations
0
(2,125)
0
0
(40)
0
(2,165)
Disposals at cost
(1,496)
(1,975)
(70)
(353)
(25)
(501)
(4,420)
Assets reclassified to held for sale
0
(1,010)
(563)
0
0
(91)
(1,664)
Foreign currency translation effects
(13)
(4,052)
(220)
(6)
(130)
(77)
(4,497)
Cost at 31 December 2021
1,335
183,358
8,481
596
12,614
5,850
212,234
Accumulated depreciation and impairment
losses at 1 January 2021
(2,596)
(132,427)
(8,005)
(524)
(1,275)
(2,251)
(147,079)
Depreciation
(68)
(9,136)
(232)
(42)
0
(930)
(10,408)
Impairment losses
(42)
(2,092)
(401)
(21)
(390)
(17)
(2,962)
Reversal of impairment losses
0
1,675
0
0
0
2
1,677
Transfers
6)
61
(1,319)
0
(61)
1,319
(11)
(11)
Accumulated depreciation and impairment
on disposed assets
1,448
1,785
59
326
21
480
4,118
Accumulated depreciation and impairment
assets classified as held for sale
0
825
461
0
0
82
1,367
Foreign currency translation effects
9
2,926
192
2
(18)
27
3,138
Accumulated depreciation and impairment
losses at 31 December 2021
5)
(1,188)
(137,763)
(7,926)
(320)
(344)
(2,619)
(150,159)
Carrying amount at 31 December 2021
147
45,595
555
276
12,270
3,231
62,075
Estimated useful lives (years)
 
3 - 20
UoP
1)
 
15 - 20
 
10 - 33
2)
 
1 - 20
3)
1)
Depreciation according to unit of production method.
2)
 
Land is not depreciated
.
Buildings include leasehold improvements.
3)
 
Depreciation linearly over contract period.
4)
 
Right of use assets at 31 December 2022 mainly consist of Land and buildings USD
1,013
 
million, Vessels USD
1,557
 
million
and Drilling rigs USD
595
 
million.
5)
 
See note 14 Impairments.
6)
 
The carrying amount of assets transferred to Property plant and equipment from Intangible assets
in 2022 and 2021 amounted to
USD
982
 
million and USD
1,730
 
million, respectively.
 
102
 
Equinor, Annual Report on Form 20-F 2022
 
13 Intangible assets
Accounting policies
Intangible assets including goodwill
Intangible assets are stated at cost, less accumulated amortisation and impairment. Intangible
 
assets include acquisition cost for oil
and gas prospects, expenditures on the exploration for and evaluation of oil and natural gas resources,
 
goodwill, and other intangible
assets. Intangible assets relating to expenditures on the exploration for and evaluation of oil
 
and natural gas resources are not
amortised. When the decision to develop a particular area is made, related intangible
 
exploration and evaluation assets are
reclassified to Property, plant and equipment.
Goodwill acquired in a business combination is allocated to each cash generating unit (CGU), or
 
group of units, expected to benefit
from the combination’s synergies. Following initial recognition, goodwill is measured at cost less any accumulated impairment
 
losses.
In acquisitions made on a post-tax basis according to the rules on the NCS, a provision
 
for deferred tax is reflected in the accounts
based on the difference between the acquisition cost and the tax depreciation basis transferred from the seller. The offsetting entry to
such deferred tax amounts is reflected as goodwill, which is allocated to the CGU or group
 
of CGUs on whose tax depreciation basis
the deferred tax has been computed.
Other intangible assets with a finite useful life, are depreciated over their useful life using the straight-line
 
method.
Oil and gas exploration, evaluation and development expenditures
Equinor uses the successful efforts method of accounting for oil and gas exploration costs. Expenditures to acquire
 
mineral interests
in oil and gas properties, including signature bonuses, expenditures to drill and equip exploratory wells
 
and evaluation expenditures
are capitalised within Intangible assets as Exploration expenditures and Acquisition costs - oil and gas
 
prospects. Geological and
geophysical costs and other exploration and evaluation expenditures are expensed as incurred.
Exploration wells that discover potentially economic quantities of oil and natural gas remain
 
capitalised as intangible assets during the
evaluation phase of the discovery. This evaluation is normally finalised within one year after well completion. If, following the
evaluation, the exploratory well has not found potentially commercial quantities of hydrocarbons,
 
the previously capitalised costs are
evaluated for derecognition or tested for impairment. Any derecognition or impairment is
 
classified as Exploration expenses in the
Consolidated statement of income.
Capitalised exploration and evaluation expenditures related to offshore wells that find proved reserves, are transferred to Property,
plant and equipment at the time of sanctioning of the development project. The timing from evaluation
 
of a discovery until a project is
sanctioned could take several years depending on the location and maturity, including existing infrastructure, of the area of discovery,
whether a host government agreement is in place, the complexity of the project and the
 
financial robustness of the project. For
onshore wells where no sanction is required, the transfer to Property, plant and equipment occurs at the time when a well is ready for
production.
For exploration and evaluation asset acquisitions (farm-in arrangements) in which Equinor has decided to fund
 
a portion of the selling
partner's exploration and/or future development expenditures (carried interests), these expenditures are reflected
 
in the Consolidated
financial statements as and when the exploration and development work progresses.
Equinor reflects exploration and evaluation asset disposals (farm-out arrangements) on a historical cost basis with no gain
 
or loss
recognition. Consideration from the sale of an undeveloped part of an asset reduces the carrying
 
amount of the asset. If the
consideration exceeds the carrying amount of the asset, the excess amount is reflected in the
 
Consolidated statement of income
under Other income. Equal-valued exchanges (swaps) of exploration and evaluation assets with
 
only immaterial cash considerations
are accounted for at the carrying amounts of the assets given up with no gain or loss recognition.
Estimation uncertainty regarding exploration activities
Exploratory wells that have found reserves, but where classification of those reserves as
 
proved depends on whether a major capital
expenditure can be justified, will remain capitalised during the evaluation phase for the findings on the
 
exploration wells. Thereafter it
will be considered a trigger for impairment evaluation of the well if no development decision is
 
planned for the near future, and there
moreover are no concrete plans for future drilling in the licence. Judgements as to whether these
 
expenditures should remain
capitalised, be derecognised or impaired in the period may materially affect the carrying values of these assets and consequently, the
operating income for the period.
------------------------------------------------------------------------------------------------------------------------------
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
103
(in USD million)
Exploration
expenses
Acquisition
costs - oil and
gas prospects
Goodwill
Other
Total
Cost at 1 January 2022
1,958
2,670
1,467
722
6,816
Additions
227
4
36
57
324
Disposals at cost
(10)
(50)
0
1
(58)
Transfers
(227)
(516)
0
(239)
(982)
Expensed exploration expenditures previously capitalised
(283)
(59)
0
0
(342)
Impairment of goodwill
0
0
(3)
0
(3)
Foreign currency translation effects
(65)
(14)
(121)
(13)
(213)
Cost at 31 December 2022
1,599
2,035
1,380
528
5,542
Accumulated depreciation and impairment losses
 
at 31 December
2022
1)
(384)
(384)
Carrying amount at 31 December 2022
1,599
2,035
1,380
144
5,158
(in USD million)
Exploration
expenses
Acquisition
costs - oil and
gas prospects
Goodwill
Other
Total
Cost at 1 January 2021
2,261
3,932
1,481
831
8,505
Additions
191
36
61
90
378
Disposals at cost
(22)
1
(3)
(29)
(53)
Transfers
(432)
(1,137)
0
(161)
(1,730)
Expensed exploration expenditures previously capitalised
(19)
(152)
0
0
(171)
Impairment of goodwill
0
0
(1)
0
(1)
Foreign currency translation effects
(21)
(10)
(70)
(10)
(111)
Cost at 31 December 2021
1,958
2,670
1,467
722
6,816
Accumulated depreciation and impairment losses
 
at 31 December
2021
1)
(364)
(364)
Carrying amount at 31 December 2021
1,958
2,670
1,467
358
6,452
1) See note 14 Impairments.
Goodwill of USD
1,380
 
million per 31 December 2022 mainly consist of technical goodwill related to business
 
acquisitions in 2019,
USD
550
 
million in the Exploration & Production Norway area and USD
410
 
million in the Marketing Midstream & Processing area.
The table below shows the aging of capitalised exploration expenditures.
(in USD million)
2022
2021
Less than one year
250
234
Between one and five years
340
692
More than five years
1,009
1,033
Total capitalised exploration expenditures
1,599
1,958
 
 
 
 
 
 
 
 
 
 
 
104
 
Equinor, Annual Report on Form 20-F 2022
 
The table below shows the components of the exploration
 
expenses.
Full year
(in USD million)
2022
2021
2020
Exploration expenditures
1,087
1,027
1,371
Expensed exploration expenditures previously capitalised
342
171
2,506
Capitalised exploration
(224)
(194)
(394)
Exploration expenses
1,205
1,004
3,483
14 Impairments
Accounting policies
Impairment of property, plant and equipment, right-of-use assets and intangible assets including goodwill
Equinor assesses individual assets or groups of assets for impairment whenever events or changes in
 
circumstances indicate that the
carrying value of an asset may not be recoverable. Assets are grouped into cash generating units (CGUs) which
 
are the smallest
identifiable groups of assets that generate cash inflows that are largely independent of the
 
cash inflows from other groups of assets.
Normally, separate CGUs are individual oil and gas fields or plants. Each unconventional asset play is considered a single CGU when
no cash inflows from parts of the play can be reliably identified as being largely independent
 
of the cash inflows from other parts of the
play. In impairment evaluations, the carrying amounts of CGUs are determined on a basis consistent with that of the recoverable
amount.
Unproved oil and gas properties are assessed for impairment when facts and circumstances
 
suggest that the carrying amount of the
asset or CGU to which the unproved properties belong may exceed its recoverable amount,
 
and at least once a year. Exploratory
wells that have found reserves, but where classification of those reserves as proved depends on
 
whether major capital expenditure
can be justified or where the economic viability of that major capital expenditure depends on the
 
successful completion of further
exploration work, will remain capitalised during the evaluation phase for the exploratory finds. If,
 
following evaluation, an exploratory
well has not found proved reserves, the previously capitalised costs are tested for impairment. After the
 
initial evaluation phase for a
well, it will be considered a trigger for impairment testing of a well if no development
 
decision is planned for the near future and there
is no firm plan for future drilling in the licence.
Goodwill is reviewed for impairment annually or more frequently if events or changes in circumstances
 
indicate that the carrying value
may be impaired. Impairment is determined by assessing the recoverable amount of the CGU,
 
or group of units, to which the goodwill
relates. When impairment testing goodwill originally recognised as an offsetting item to the computed deferred
 
tax provision in a post-
tax transaction on the NCS, the remaining amount of the deferred tax provision will factor
 
into the impairment evaluations.
Impairment losses and reversals of impairment losses are presented in the Consolidated statement
 
of income as Exploration
expenses or Depreciation, amortisation and net impairment losses, on the basis of the nature of the impaired
 
assets as either
exploration assets (intangible exploration assets) or development and producing assets (property, plant and equipment and other
intangible assets), respectively.
Measurement
The recoverable amount applied in Equinor’s impairment assessments is normally estimated value
 
in use. Equinor may also apply the
assets’ fair value less cost of disposal as the recoverable amount when such a value is available,
 
reasonably reliable,
 
and based on a
recent and comparable transaction.
Value in use is determined using a discounted cash flow model. The estimated future cash flows are based on reasonable and
supportable assumptions and represent management's best estimates of the range of economic
 
conditions that will exist over the
remaining useful life of the assets, as set down in Equinor's most recently approved forecasts. Assumptions
 
and economic conditions
in establishing the forecasts are reviewed by management on a regular basis and updated at least annually. For assets and CGUs
with an expected useful life or timeline for production of expected oil and natural gas reserves
 
extending beyond five years, including
planned onshore production from shale assets with a long development and production horizon, the forecasts
 
reflect expected
production volumes, and the related cash flows include project or asset specific estimates reflecting
 
the relevant period. Such
estimates are established based on Equinor's principles and assumptions and are consistently applied.
The estimated future cash flows are adjusted for risks specific to the asset or CGU and discounted
 
using a real post-tax discount rate
which is based on Equinor's post-tax weighted average cost of capital (WACC). Country risk specific to a project is included as a
monetary adjustment to the projects’ cash flow. Equinor considers country risk primarily as an unsystematic risk. The cash flow is
adjusted for risk that influences the expected cash flow of a project and which is not part of the
 
project itself. The use of post-tax
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
105
discount rates in determining value in use does not result in a materially different determination of the need for, or the amount of,
impairment that would be required if pre-tax discount rates had been used.
Impairment reversals
A previously recognised impairment loss is reversed only if there has been a change in the estimates used to
 
determine the asset’s
recoverable amount since the last impairment loss was recognised. A reversal cannot exceed the
 
carrying amount of the asset or
CGU that would have been reflected, net of depreciation, if no impairment loss had been recognised
 
in prior periods. Impairment of
unsuccessful wells is reversed only to the extent that conditions for impairment are no longer present.
 
Previously recognised
impairments of goodwill are not reversed in future periods.
Estimation uncertainty regarding impairment
Evaluating whether an asset is impaired or if an impairment should be reversed requires a
 
high degree of judgement and may to a
large extent depend upon the selection of key assumptions about the future. In Equinor's
 
line of business, judgement is involved in
determining what constitutes a CGU. Development in production, infrastructure solutions, markets, product
 
pricing, management
actions and other factors may over time lead to changes in CGUs such as splitting one original CGU
 
into several CGUs.
The key assumptions used will bear the risk of change based on the inherent volatile nature of macro-economic
 
factors such as future
commodity prices and discount rates, and uncertainty in asset specific factors such as reserve
 
estimates and operational decisions
impacting the production profile or activity levels for our oil and natural gas properties. Changes in foreign
 
currency exchange rates
will also affect value in use, especially for assets on the NCS, where the functional currency is NOK. When estimating
 
the recoverable
amount, the expected cash flow approach is applied to reflect uncertainties in timing and amounts inherent
 
in the assumptions used in
the estimated future cash flows. For example, climate-related matters (see also Note 3 Consequences of initiatives
 
to limit climate
changes) are expected to have a pervasive effect on the energy industry, affecting not only supply, demand and commodity prices,
but also technology changes, increased emission-related levies,
 
and other matters with mainly mid-term and long-term effects. These
effects have been factored into the price assumptions used for estimating future cash flows using
 
probability-weighted scenario
analyses.
The estimated future cash flows, reflecting Equinor’s, market participants’ and other external
 
sources’ assumptions about the future
and discounted to their present value, involve complexity. In order to establish relevant future cash flows, impairment testing requires
long-term assumptions to be made concerning a number of economic factors such as future market prices,
 
refinery margins, foreign
currency exchange rates and future output, discount rates, impact of the timing of tax incentive
 
regulations, and political and country
risk among others. Long-term assumptions for major economic factors are made at a group level, and
 
there is a high degree of
reasoned judgement involved in establishing these assumptions, in determining other relevant factors
 
such as forward price curves, in
estimating production outputs, and in determining the ultimate terminal value of an asset.
------------------------------------------------------------------------------------------------------------------------------
Net impairments/(reversal of impairments)
Full year
Property, plant and equipment
 
Intangible assets
 
Total
(in USD million)
2022
2021
2020
2022
2021
2020
2022
2021
2020
Producing and development assets
1)
(3,313)
1,285
5,671
(26)
(2)
680
(3,339)
1,283
6,351
Goodwill
1)
3
1
42
3
1
42
Other intangible assets
1)
0
0
8
0
0
8
Acquisition costs related to oil and gas prospects
2)
85
154
657
85
154
657
Total net impairments/(reversals) recognised for
Property, plant and equipment and Intangible assets
(3,313)
1,285
5,671
62
154
1,386
(3,251)
1,439
7,057
1)
 
In addition, impairments in 2022 related to equity accounted investments amounted to USD
832
 
million, please refer to note 6
Acquisitions and disposals regarding the effects of the decision to exit Russia. The total net impairment reversals recognised
 
under
IAS 36 Impairment of assets in 2022 amount to USD
2,504
 
million.
 
2)
 
Subject to impairment assessment under the successful efforts’ method (IFRS 6 Exploration and Evaluation
 
of Mineral Resources)
and classified as exploration expenses in the income statement.
 
 
 
 
 
 
 
 
 
 
 
 
 
106
 
Equinor, Annual Report on Form 20-F 2022
 
For impairment purposes, the asset’s carrying amount is compared to its recoverable amount. The table below describes,
 
per area,
the Producing and development assets being impaired/(reversed),
 
net impairment/(reversal), and the carrying amount after
impairment.
At 31 December 2022
At 31 December 2021
(in USD million)
Carrying
amount after
impairment
 
Net impairment
loss/ (reversal)
Carrying
amount after
impairment
 
Net impairment
loss/ (reversal)
Exploration & Production Norway
3,201
(819)
5,379
(1,102)
Exploration & Production USA - onshore
546
(204)
1,979
48
Exploration & Production USA - offshore Gulf of Mexico
2,691
(882)
798
18
Europe and Asia
1,551
295
1,566
1,609
Marketing, Midstream & Processing
1,416
(895)
868
716
Other
30
0
20
(7)
Total
9,435
(2,505)
10,611
1,283
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
107
Exploration & Production Norway
In 2022, the net impairment reversal was mainly caused by increased price estimates and changed
 
gas export strategy. In 2021, the
net impairment reversal was mainly due to increased price estimates and an upward reserve revision.
Exploration & Production USA - onshore
In 2022, the impairment reversal was caused by increased gas price assumptions,
 
while in 2021 the net impairment was caused by
revision of reserves and sale of an asset.
Exploration & Production USA - offshore Gulf of Mexico
In 2022, the impairment reversal was caused by increased price assumptions and higher reserves estimates, while
 
in 2021, the
impairment was due to a negative reserve revision.
Exploration & Production International – Europe and Asia
In 2022, the net impairment was mainly caused by the decision to exit Russia (see note 6 Acquisitions
 
and disposals). This was to a
large extent offset by a reversal on Mariner in the UK mainly due to optimisation of the production
 
profile and higher prices, supported
by a slight increase in reserves estimates. In 2021, the net impairment was mainly caused by downward
 
reserve revisions partially
offset by higher prices.
Marketing, Midstream & Processing
In 2022 the net impairment reversal was mainly related to increased refinery margin assumptions,
 
while in 2021, the impairment
losses were caused by increased CO
2
 
fees and – quotas on a refinery and a classification to held for sale.
Accounting assumptions
Management’s future commodity price assumptions and currency assumptions are applied when estimating value in
 
use. While there
are inherent uncertainties in the assumptions, the commodity price assumptions as well
 
as currency assumptions reflect
management’s best estimate of the price and currency development over the life of the Group’s assets based on its view of relevant
current circumstances and the likely future development of such circumstances, including energy demand
 
development, energy and
climate change policies as well as the speed of the energy transition, population and economic growth,
 
geopolitical risks, technology
and cost development and other factors. Management’s best estimate also takes into consideration a range of external
 
forecasts.
Equinor has performed a thorough and broad analysis of the expected development in drivers for
 
the different commodity markets and
exchange rates. Significant uncertainty exists regarding future commodity price development due to the transition
 
to a lower carbon
economy, future supply actions by OPEC+ and other factors. The management’s analysis of the expected development in drivers for
the different commodity markets and exchange rates resulted in changes in the long-term price assumptions with effect from the third
quarter of 2022. The main changes with effect for impairment and impairment reversal assessments are disclosed
 
in the table below
as price-points on price-curves. Previously applied price-points from the third quarter of 2021 up
 
to and including the second quarter
of 2022 are provided in brackets.
Year
Prices in real term 1)
2025
2030
2040
2050
Brent Blend (USD/bbl)
75
(70)
75
(75)
70
(69)
65
(64)
European gas (USD/MMBtu) - TTF
 
2)
20.0
(7.3)
9.5
(6.8)
9.0
(8.2)
9.0
(7.5)
Henry Hub (USD/MMBtu)
4.0
(3.3)
3.7
(3.4)
3.7
(3.6)
3.7
(3.6)
Electricity Germany (EUR/MWh)
115
(65)
70
(62)
57
(64)
57
(64)
EU ETS (EUR/tonne)
80
(61)
80
(70)
105
(89)
130
(108)
1)
Basis year 2022. The prices in the table are price-points on price-curves.
2)
 
As from the third quarter 2022, TTF is applied as the main reference price for European
 
gas. Updated price-points for the
previously applied NBP correspond to the disclosed updated price-points for TTF. Previously applied comparable prices for
NBP are
7.4
,
6.9
,
8.3
 
and
7.6
 
for 2025, 2030, 2040 and 2050 respectively.
Climate considerations are included in the impairment calculations directly by estimating the CO
2
 
taxes in the cash flows. Indirectly,
the expected effect of climate change is also included in the estimated commodity prices where supply and demand
 
are considered.
The prices also have effect on the estimated production profiles and economic cut-off of the projects. Furthermore, climate
considerations are a part of the investment decisions following Equinor’s strategy
 
and commitments to the energy transition.
Norway’s Climate Action Plan for the period 2021-2030 (Meld. St 13 (2020-2021)) which assumes
 
a gradually increased CO
2
 
tax (the
total of EU ETS + Norwegian CO
2
 
tax) in Norway to
2,000
 
NOK/tonne in 2030 is used for impairment calculations of Norwegian
upstream assets.
108
 
Equinor, Annual Report on Form 20-F 2022
 
To reflect that carbon will have a cost for all our assets the current best estimate is considered to be EU ETS for countries outside EU
where carbon is not already subject to taxation or where Equinor has not established specific estimates.
The long-term NOK currency exchange rates are expected to be unchanged compared to previous
 
long-term assumptions. The
NOK/USD rate from 2025 and onwards is kept at
8.50
, the NOK/EUR at
10.0
. The USD/GBP rate is kept at
1.35
.
The base discount rate applied in value in use calculations is
5.0
% real after tax. The discount rate is derived from Equinor’s weighted
average cost of capital. For projects, mainly within the REN segment in periods with
 
fixed low risk income,
 
a lower discount rate will be
considered. A derived pre-tax discount rate is in the range of
42
-
102
% for E&P Norway,
8
-
9
% for E&P International,
6
-
9
% for E&P
USA and
7
% for MMP depending on the asset’s characteristics, such as specific tax treatments, cash flow profiles,
 
and economic life.
The pre-tax rates for 2021 were
18
-
32
%,
5
-
9
%,
6
-
7
% and
7
% respectively.
Sensitivities
Commodity prices have historically been volatile. Significant downward adjustments of Equinor’s
 
commodity price assumptions would
result in impairment losses on certain producing and development assets in Equinor’s
 
portfolio including intangible assets that are
subject to impairment assessment, while an opposite adjustment could lead to impairment-reversals. If
 
a decline in commodity price
forecasts over the lifetime of the assets was
30
%, considered to represent a reasonably possible change, the impairment amount
 
to
be recognised could illustratively be in the region of USD
14
 
billion before tax effects. See note 3 Consequences of initiatives to limit
climate changes for possible effect of using the prices in a 1.5
o
C compatible Net Zero Emission by 2050 scenario and the Announced
Pledges Scenario as estimated by the International Energy Agency (IEA).
These illustrative impairment sensitivities, both based on a simplified method, assumes no changes to
 
input factors other than prices;
however, a price reduction of
30
% or those representing Net Zero Emission scenario and Announced Pledges Scenario is
 
likely to
result in changes in business plans as well as other factors used when estimating an asset’s recoverable
 
amount. These associated
changes reduce the stand-alone impact on the price sensitivities. Changes in such input factors would likely include
 
a reduction in the
cost level in the oil and gas industry as well as offsetting foreign currency effects, both of which have historically occurred following
significant changes in commodity prices. The illustrative sensitivities are therefore not considered to
 
represent a best estimate of an
expected impairment impact, nor an estimated impact on revenues or operating income in such
 
a scenario. A significant and
prolonged reduction in oil and gas prices would also result in mitigating actions by Equinor and its
 
licence partners, as a reduction of
oil and gas prices would impact drilling plans and production profiles for new and existing assets.
 
Quantifying such impacts is
considered impracticable, as it requires detailed technical, geological and economical evaluations
 
based on hypothetical scenarios
and not based on existing business or development plans.
Equinor, Annual Report on Form 20-F 2022
 
109
15 Joint arrangements and associates
Accounting policies
Joint operations and similar arrangements, joint ventures and associates
A joint arrangement is a contractual arrangement whereby Equinor and other parties undertake an
 
activity subject to joint control, i.e.
when decisions about the relevant activities require the unanimous consent of the parties
 
sharing control. Such joint arrangements are
classified as either joint operations or joint ventures. In determining the appropriate classification, Equinor
 
considers the nature of
products and markets of the arrangements and whether the substance of the agreements is
 
that the parties involved have rights to
substantially all the arrangement's assets and obligations for the liabilities, or whether the parties involved have
 
rights to the net
assets of the arrangement. Equinor accounts for its share of assets, liabilities, revenues
 
and expenses in joint operations in
accordance with the principles applicable to those particular assets, liabilities, revenues and expenses.
Those of Equinor's exploration and production licence activities that are within the scope
 
of IFRS 11 Joint Arrangements have been
classified as joint operations. A considerable number of Equinor's unincorporated joint exploration
 
and production activities are
conducted through arrangements that are not jointly controlled, either because unanimous consent is not
 
required among all parties
involved, or no single group of parties has joint control over the activity. Licence activities where control can be achieved through
agreement between more than one combination of involved parties are considered to be outside
 
the scope of IFRS 11, and these
activities are accounted for on a pro-rata basis using Equinor's ownership share. Currently, Equinor uses IFRS 11 by analogy for all
such unincorporated licence arrangements whether these are in scope of IFRS 11 or not. Reference is made to note 5 Segments for
financial information related to Equinor’s participation in joint operations within
 
upstream activities.
Joint ventures, in which Equinor has rights to the net assets, are accounted for using the equity method. These
 
currently include the
majority of Equinor’s investments in the Renewables (REN) operating and reporting
 
segment. Equinor’s participation in joint
arrangements that are joint ventures and investments in companies in which Equinor has neither
 
control nor joint control but has the
ability to exercise significant influence over operating and financial policies, are classified as
 
equity accounted investments.
Under the equity method, the investment is carried on the Consolidated balance sheet at cost
 
plus post-acquisition changes in
Equinor’s share of net assets of the entity, less distributions received and less any impairment in value of the investment. The part of
an equity accounted investment’s dividend distribution exceeding the entity’s carrying amount in the Consolidated balance sheet
 
is
reflected as income from equity accounted investments in the Consolidated statement of income.
 
Equinor will subsequently only
reflect the share of net profit in the investment that exceeds the dividend already reflected as income. The
 
Consolidated statement of
income reflects Equinor’s share of the results after tax of an equity accounted entity, adjusted to account for depreciation, amortisation
and any impairment of the equity accounted entity’s assets based on their fair values at the date of acquisition. Net
 
income/loss from
equity accounted investments is presented as part of Total revenues and other income, as investments in and participation with
significant influence in other companies engaged in energy-related business activities is considered to be
 
part of Equinor’s main
operating activities.
Acquisition of ownership shares in joint ventures and other equity accounted investments in which the
 
activity constitutes a business,
are accounted for in accordance with the requirements applicable to business combinations. Please
 
refer to note 6 Acquisitions and
disposals for more details on acquisitions.
Equinor as operator of joint operations and similar arrangements
Indirect operating expenses such as personnel expenses are accumulated in cost pools. These costs
 
are allocated on an hours’
incurred basis to business areas and Equinor-operated joint operations under IFRS 11 and to similar arrangements (licences) outside
the scope of IFRS 11. Costs allocated to the other partners' share of operated joint operations and similar arrangements are
reimbursed and only Equinor's share of the statement of income and balance sheet items related
 
to Equinor-operated joint operations
and similar arrangements are reflected in the Consolidated statement of income and the Consolidated
 
balance sheet.
-----------------------------------------------------------------------------------------------------------------------------
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
110
 
Equinor, Annual Report on Form 20-F 2022
 
Joint ventures and other equity accounted investme
 
nts
(in USD million)
2022
2021
Net investments at 1 January
2,686
2,270
Net income/(loss) from equity accounted investments
620
259
Impairment
1)
(832)
0
Acquisitions and increase in capital
337
475
Dividend and other distributions
(210)
(230)
Other comprehensive income/(loss)
384
(58)
Divestments, derecognition and decrease in paid in
 
capital
(22)
(31)
Other
(205)
1
Net investments at 31 December
2,758
2,686
1) Related to investments in Russia, see also note 6 Acquisitions and disposals.
Equity accounted investments consist of several investments, none above USD
0.6
 
billion. None of the investments are significant on
an individual basis. Voting rights corresponds to ownership.
16 Financial investments and financial receivables
Non-current financial investments
At 31 December
(in USD million)
2022
2021
Bonds
1,448
1,822
Listed equity securities
794
1,131
Non-listed equity securities
491
393
Financial investments
2,733
3,346
Bonds and equity securities mainly relate to investment portfolios held by Equinor’s
 
captive insurance company and other listed and
non-listed equities held for long-term strategic purposes, mainly accounted for using fair value through
 
profit or loss.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
111
Non-current prepayments and financial receivables
At 31 December
(in USD million)
2022
2021
Interest-bearing financial receivables
 
1,658
707
Other interest-bearing receivables
66
276
Prepayments and other non-interest-bearing receivables
339
104
Prepayments and financial receivables
2,063
1,087
Interest-bearing financial receivables consist primarily of receivables
 
from related parties, see note 27 Related parties. Other interest-
bearing receivables primarily relate to financial sublease and tax receivables.
Current financial investments
At 31 December
(in USD million)
2022
2021
Time deposits
12,373
7,060
Interest-bearing securities
17,504
14,186
Financial investments
29,876
21,246
At 31 December 2022, current financial investments
include USD
410
 
million in investment portfolios held by Equinor’s captive
insurance company which mainly are accounted for using fair value through profit or loss.
 
The corresponding balance at 31 December
2021 was USD
300
 
million.
For information about financial instruments by category, see note 28
Financial instruments and fair value measurement
.
 
 
 
 
 
 
 
 
 
 
 
112
 
Equinor, Annual Report on Form 20-F 2022
 
17 Inventories
Accounting policies
Inventories
Commodity inventories not held for trading purposes are stated at the lower of cost and net realisable
 
value. Cost is determined by the
first-in first-out method and comprises direct purchase costs, cost of production, transportation, and manufacturing
 
expenses. With
effect from 2022, due to the evolving trading business in the Group, fair value less cost to sell (FVLCS)
 
is considered the appropriate
measurement basis for commodity inventories held for trading purposes, with subsequent changes in
 
FV recognised in the
Consolidated statement of income under Other revenues. These inventories are categorised within level
 
2 of the fair value hierarchy.
Comparative numbers have not been restated due to materiality.
------------------------------------------------------------------------------------------------------------------------------
At 31 December
(in USD million)
2022
2021
Crude oil
2,115
2,014
Petroleum products
451
315
Natural gas
127
642
Commodity inventories at the lower of cost and net
 
realisable value
2,693
2,971
Natural gas held for trading purposes measured
 
at fair value
1,994
0
Other
517
424
Total inventories
5,205
3,395
The write-down of inventories from cost to net realisable value amounted to an expense of USD
143
 
million and USD
77
 
million in
2022 and 2021, respectively. Inventories held for trading purposes consist of gas stores held by Danske Commodities.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
113
18 Trade and other receivables
At 31 December
(in USD million)
2022
2021
Trade receivables from contracts with customers
1)
15,213
13,266
Other current receivables
992
1,436
Collateral receivables
2)
3,468
1,576
Receivables from participation in joint operations and
 
similar arrangements
661
491
Receivables from equity accounted associated companies
 
and other related parties
1,276
423
Total financial trade and other receivables
21,611
17,192
Non-financial trade and other receivables
841
736
Trade and other receivables
22,452
17,927
1) Trade receivables from contracts with customers are shown
 
net of an immaterial provision for expected
 
losses.
2) Mainly related to cash paid as security for
 
a portion of Equinor's credit exposure.
 
For more information about the credit quality of Equinor's counterparties, see note 4 Financial
 
risk and capital management. For
currency sensitivities, see note 28 Financial instruments and fair value measurement.
19 Cash and cash equivalents
Accounting policies
Cash and cash equivalents are accounted for at amortised cost and include cash in hand, current
 
balances with banks and similar
institutions, and short-term highly liquid investments that are readily convertible to known amounts
 
of cash, are subject to an
insignificant risk of changes in fair value and have a maturity of three months or less from the
 
acquisition date. Contractually
mandatory deposits in escrow bank accounts are included as restricted cash if the deposits are
 
provided as part of the Group’s
operating activities and therefore are deemed as held for the purpose of meeting short
‑
term cash commitments, and the deposits can
be released from the escrow account without undue expenses.
At 31 December
(in USD million)
2022
2021
Cash at bank available
2,220
2,673
Time deposits
836
1,906
Money market funds
3,106
2,714
Interest-bearing securities
3,276
4,740
Restricted cash, including collateral deposits
6,140
2,093
Cash and cash equivalents
15,579
14,126
Restricted cash at 31 December 2022 includes collateral deposits of USD
6,128
 
million related to trading activities. Correspondingly,
collateral deposits at 31 December 2021 were USD
2,069
 
million. Collateral deposits are related to certain requirements of exchanges
where Equinor is trading. The terms and conditions related to these requirements are
 
determined by the respective exchanges.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
114
 
Equinor, Annual Report on Form 20-F 2022
 
20 Shareholders' equity and dividends
Number of
shares
NOK per value
NOK
USD
Share capital at 1 January 2022
3,257,687,707
 
2.50
 
8,144,219,267.50
 
1,163,987,792
 
Capital reduction
(82,217,548)
2.50
 
(205,543,870.00)
(21,951,527)
Share capital at 31 December 2022
3,175,470,159
 
2.50
 
7,938,675,397.50
 
1,142,036,265
 
Number of
shares
NOK per value
Common Stock
Authorised and issued
3,175,470,159
 
2.50
 
7,938,675,397.50
 
Treasury shares
Share buy-back programme
(42,619,172)
2.50
 
(106,547,930.00)
Employees share saving plan
(10,908,717)
2.50
 
(27,271,792.50)
Total outstanding shares
3,121,942,270
 
2.50
 
7,804,855,675.00
 
Equinor ASA has only one class of shares and all shares have voting rights. The holders
 
of shares are entitled to receive dividends as
and when declared and are entitled to one vote per share at the annual general
 
meeting of the company.
Dividend
During 2022, dividend for the third and for the fourth quarter of 2021 and dividend for
 
the first and second quarter of 2022 were
settled. Dividend declared but not yet settled is presented as dividends payable in the Consolidated
 
balance sheet. The Consolidated
statement of changes in equity shows declared dividend in the period (retained earnings). Dividend
 
declared in 2022 relates
 
to the
fourth quarter of 2021 and to the first three quarters of 2022.
On 7 February 2023, the board of directors proposed an ordinary cash dividend for the fourth
 
quarter of 2022 of USD
0.30
 
per share
and an extraordinary cash dividend of USD
0.60
 
per share (subject to annual general meeting approval). The Equinor share will
 
trade
ex-dividend 11 May 2023 on Oslo Børs and for ADR holders on New York Stock Exchange. Record date will be 12 May 2023 and
payment date will be 25 May 2023.
At 31 December
(in USD million)
2022
2021
Dividends declared
7,549
 
2,041
 
USD per share or ADS
2.4000
 
0.6300
 
Dividends paid
5,380
 
1,797
 
USD per share or ADS
1.6800
 
0.5600
 
NOK per share
16.4837
 
4.8078
 
-------------------------------------------------------------------------------------------------------------------------------------
Accounting policies
Share buy-back
Where Equinor has either acquired own shares under a share buy-back programme or
 
has placed an irrevocable order with a third
party for Equinor shares to be acquired in the market, such shares are reflected
 
as a reduction in equity as treasury shares. Treasury
shares are not included in the weighted average number of ordinary shares outstanding in the
 
calculation of Earnings per share. The
remaining outstanding part of an irrevocable order to acquire shares is accrued for and classified as Trade, other payables and
provisions.
-------------------------------------------------------------------------------------------------------------------------------------
Share buy-back programme
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
115
The purpose of the share buy-back programme is to reduce the issued share capital
 
of the company. All shares repurchased as part
of the programme will be cancelled. According to an agreement between Equinor and the Norwegian
 
State, the Norwegian State will
participate in share buy-backs on a proportionate basis, ensuring that its ownership interest
 
in Equinor remains unchanged at
67
%.
On 7 February 2023, the board proposed an annual share buy-back programme for 2023 with
 
up to USD
6,000
 
million, including
shares to be redeemed from the Norwegian State, subject to authorisation from the annual general
 
meeting. The annual share buy-
back programme is expected to be executed when Brent Blend oil price is in or above the range
 
of
50
-
60
 
USD/bbl, Equinor’s net debt
to capital employed adjusted* stays within the communicated ambition of
15
-
30
 
% and this is supported by commodity prices.
On 7 February 2023, the board of directors resolved the commencement of the first tranche
 
of the share buy-back programme for
2023 of a total of USD
1,000
 
million, including shares to be redeemed from the Norwegian State. The first tranche
 
will end no later
than 24 March 2023
.
Number of shares
2022
2021
Share buy-back programme at 1 January
13,460,292
 
-
 
Purchase
56,290,671
 
13,460,292
 
Cancellation
(27,131,791)
-
 
Share buy-back programme at 31 December
42,619,172
 
13,460,292
 
Equity impact of share buy back programmes
(in USD million)
2022
2021
First tranche
330
 
99
 
Second tranche
440
 
330
 
Third tranche
605
 
-
 
Fourth tranche
605
 
-
 
Norwegian state share
1)
1,399
 
-
 
Total
3,380
 
429
 
1) Relates to the 2021 programme and first tranche of 2022 programme.
In February 2022, Equinor launched a share buy-back programme for 2022 of up to USD
5,000
 
million, where the first tranche of
around USD
1,000
 
million was finalised in March 2022. USD
330
 
million of the first tranche was acquired in the open market. The
redemption of the proportionate share of
67
% from the Norwegian State was approved by the annual general meeting 11 May 2022
and settled in July 2022 as described below.
In May 2022, Equinor launched the second tranche of USD
1,333
 
million of the 2022 share buy-back programme of which USD
440
million was purchased in the open market. The acquisition of the second tranche in the
 
open market was finalised in July 2022.
In July 2022, Equinor increased the target level of share buy-back for 2022 from USD
5,000
 
million up to USD
6,000
 
million and
launched the third tranche of USD
1,833
 
million. USD
605
 
million was purchased in the open market. The acquisition of the third
tranche in the open market was finalised in October 2022.
In October 2022, Equinor launched the fourth and final tranche of the share buy-back programme
 
for 2022 of USD
1,833
 
million. The
fourth tranche of USD
605
 
million (both acquired and remaining order) has been recognised as a reduction in equity
 
as treasury
shares due to an irrevocable agreement with a third party. As of 31 December 2022, USD
495
million of the fourth tranche has been
purchased in the open market, of which USD
475
 
million has been settled. The remaining order of the fourth tranche is accrued for
and classified as Trade, other payables and provisions. The acquisition of the fourth tranche in the open market was
 
finalised in
January 2023.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
116
 
Equinor, Annual Report on Form 20-F 2022
 
After having finalised the 2021 share buy-back programme as well as the first tranche
 
of the 2022 share buy-back programme in the
market in the period 28 July 2021 to 25 March 2022, a proportionate share of
67
% from the Norwegian State was redeemed in
accordance with an agreement with the Ministry of Trade, Industry and Fisheries for the Norwegian State to maintain
 
their ownership
percentage in Equinor. The redemption was approved by the annual general meeting held on 11 May 2022. The shares were
cancelled on 29 June 2022 and the liability of USD
1,399
 
million (NOK
13,496
 
million) to the Norwegian State was settled on 20 July
2022.
For the second, third and fourth tranche of the share buy-back programme of 2022, USD
3,350
 
million of shares from the Norwegian
State will, in accordance with an agreement with the Ministry of Trade, Industry and Fisheries, be redeemed at the annual general
meeting in May 2023 in order for the Norwegian State to maintain its ownership share
 
of
67
% in Equinor.
Employees share saving plan
Number of shares
2022
2021
Share saving plan at 1 January
12,111,104
 
11,442,491
 
Purchase
2,127,172
 
3,412,994
 
Allocated to employees
(3,329,559)
(2,744,381)
Share saving plan at 31 December
10,908,717
 
12,111,104
 
In 2022 and 2021 treasury shares were purchased and allocated to employees participating in the share
 
saving plan for USD
72
million and USD
75
 
million, respectively. For further information, see note 8 Salaries and personnel expenses.
21 Finance debt
Non-current finance debt
Finance debt measured at amortised cost
Weighted average interest
rates in %
1)
Carrying amount in USD
millions at 31 December
Fair value in USD
 
millions at 31 December
2)
2022
2021
2022
2021
2022
2021
Unsecured bonds
United States Dollar (USD)
3.82
3.88
17,190
17,451
16,167
19,655
Euro (EUR)
1.42
1.42
7,465
7,925
6,782
8,529
Great Britain Pound (GBP)
6.08
6.08
1,652
1,852
1,836
2,674
Norwegian Kroner (NOK)
4.18
4.18
304
340
311
380
Total unsecured bonds
26,612
27,568
25,097
31,237
Unsecured loans
Japanese Yen (JPY)
4.30
4.30
76
87
90
106
Total unsecured loans
76
87
90
106
Total
26,688
27,655
25,187
31,343
Non-current finance debt due within one year
2,547
250
2,597
268
Non-current finance debt
24,141
27,404
22,590
31,075
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
117
1)
Weighted average interest rates are calculated based on the contractual rates on the loans per currency at 31 December
 
and do
not include the effect of swap agreements.
2)
 
Fair values are determined from external calculation models based on market observations from
 
various sources, classified at
level 2 in the fair value hierarchy. For more information regarding fair value hierarchy, see note 28 Financial instruments and fair
value measurement.
Unsecured bonds amounting to USD
17,190
 
million are denominated in USD and unsecured bonds denominated in other currencies
amounting to USD
8,624
 
million are swapped into USD. One bond denominated in EUR amounting to USD
797
 
million is not
swapped. The table does not include the effects of agreements entered into to swap the various currencies into
 
USD. For further
information see note 28 Financial instruments and fair value measurement.
Substantially all unsecured bonds and unsecured bank loan agreements contain provisions restricting future pledging
 
of assets to
secure borrowings without granting a similar secured status to the existing bondholders and lenders.
No new bonds were issued in 2022.
Out of Equinor's total outstanding unsecured bond portfolio,
38
 
bond agreements contain provisions allowing Equinor to call the debt
prior to its final redemption at par or at certain specified premiums if there are changes to
 
the Norwegian tax laws. The carrying
amount of these agreements is USD
26,302
 
million at the 31 December 2022 closing currency exchange rate.
For more information about the revolving credit facility, maturity profile for undiscounted cash flows and interest rate risk management,
see note 4 Financial risk and capital management.
 
Non-current finance debt maturity profile
At 31 December
(in USD million)
2022
2021
Year 2 and 3
4,794
5,015
Year 4 and 5
4,510
4,731
After 5 years
14,837
17,659
Total repayment of non-current finance debt
24,141
27,404
Weighted average maturity (years - including current portion)
9
10
Weighted average annual interest rate (% - including current portion)
3.29
3.33
Current finance debt
At 31 December
(in USD million)
2022
2021
Collateral liabilities
1,571
2,271
Non-current finance debt due within one year
2,547
250
Other including US Commercial paper programme
 
and bank overdraft
241
2,752
Total current finance debt
4,359
5,273
Weighted average interest rate (%)
2.22
0.51
Collateral liabilities and other current liabilities mainly relate to cash received as security for
 
a portion of Equinor's credit exposure and
outstanding amounts on US Commercial paper (CP) programme. Issuance on the CP programme
 
amounted to USD
227
 
million as of
 
31 December 2022 and USD
2,600
 
million as of 31 December 2021.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
118
 
Equinor, Annual Report on Form 20-F 2022
 
Reconciliation of cash flows from financing activities
 
to finance line items in balance sheet
 
(in USD million)
Non-current
finance debt
Current
finance
debt
Financial
receivable
Collaterals
1)
Additional
paid in
capital
 
/Treasury
shares
Non-
controlling
interest
Dividend
payable
Lease
liabilities
2)
Total
At 1 January 2022
27,404
5,273
(1,577)
(2,027)
14
582
3,562
New finance debt
-
Repayment of finance debt
(250)
(250)
Repayment of lease liabilities
(1,366)
(1,366)
Dividend paid
(5,380)
(5,380)
Share buy-back
(3,315)
(3,315)
Net current finance debt and other
finance activities
(2,982)
(2,038)
(73)
(8)
(5,102)
Net cash flow from financing activities
(250)
(2,982)
(2,038)
(3,388)
(8)
(5,380)
(1,366)
(15,414)
Transfer to current portion
(2,297)
2,297
Effect of exchange rate changes
(710)
(78)
145
(3)
(149)
Dividend declared
7,549
New leases
1,644
Other changes
(7)
(151)
30
(2)
57
(24)
Net other changes
(3,014)
2,068
145
30
(5)
7,606
1,471
At 31 December 2022
24,141
4,359
(3,468)
(5,385)
1
2,808
3,667
(in USD million)
Non-current
finance debt
Current
finance
debt
Financial
receivable
Collaterals
1)
Additional
paid in
capital
 
/Treasury
shares
Non-
controlling
interest
Dividend
payable
Lease
liabilities
2)
Total
At 1 January 2021
29,118
4,591
(967)
(1,588)
19
357
4,406
New finance debt
-
Repayment of finance debt
(2,675)
(2,675)
Repayment of lease liabilities
(1,238)
(1,238)
Dividend paid
(1,797)
(1,797)
Share buy-back
(321)
(321)
Net current finance debt and other
finance activities
(335)
2,273
(651)
(75)
(18)
1,195
Net cash flow from financing activities
(3,010)
2,273
(651)
(396)
(18)
(1,797)
(1,238)
(4,836)
Transfer to current portion
1,724
(1,724)
Effect of exchange rate changes
(422)
(8)
41
(1)
(61)
Dividend declared
2,041
New leases
476
Other changes
(6)
141
-
(43)
14
(19)
(21)
Net other changes
1,296
(1,591)
41
(43)
13
2,022
394
At 31 December 2021
27,404
5,273
(1,577)
(2,027)
14
582
3,562
Equinor, Annual Report on Form 20-F 2022
 
119
1)
Financial receivable collaterals are included in Trade and other receivables in the Consolidated balance sheet. See note 18
Trade and other receivables for more information.
2)
 
See note 25 Leases for more information.
120
 
Equinor, Annual Report on Form 20-F 2022
 
22 Pensions
Accounting policies
Equinor has pension plans for employees that either provide a defined pension benefit upon retirement or a
 
pension dependent on
defined contributions and related returns. A portion of the contributions are provided
 
for as notional contributions, for which the liability
increases with a promised notional return, set equal to the actual return of assets invested through
 
the ordinary defined contribution
plan. For defined benefit plans, the benefit to be received by employees generally
 
depends on many factors including length of
service, retirement date and future salary levels.
Equinor's proportionate share of multi-employer defined benefit plans is recognised as liabilities in the Consolidated
 
balance sheet as
sufficient information is considered available, and a reliable estimate of the obligation can be made.
The cost of pension benefit plans is expensed over the period that the employees render
 
services and become eligible to receive
benefits. The calculation is performed by an external actuary. Equinor's net obligation from defined benefit pension plans is calculated
separately for each plan by estimating the amount of future benefit that employees have earned
 
in return for their services in the
current and prior periods. That benefit is discounted to determine its present value, and the fair
 
value of any plan assets is deducted.
The discount rate is the yield at the balance sheet date, reflecting the maturity dates approximating
 
the terms of Equinor's obligations.
On 31 December 2022, the discount rate for the defined benefit plans in Norway was established
 
on the basis of seven years'
mortgage covered bonds interest rate extrapolated on a yield curve which matches the duration of
 
Equinor's payment portfolio for
earned benefits, which was calculated to be 13.5 years at the end of 2022. The present
 
values of the defined benefit obligation, the
related current service cost and past service cost are measured using the projected unit credit
 
method. The assumptions for expected
wage growth, expected rate of pension increase and the expected increase of social security base
 
amount (G-amount) are based on
agreed regulation in the plans, historical observations, future expectations of the assumptions and
 
the relationship between these
assumptions. For members in Norway, the mortality table K2013, issued by The Financial Supervisory Authority of Norway, is used as
the best mortality estimate. Social security tax is calculated based on a pension plan's net funded status
 
and is included in the defined
benefit obligation.
The recognition of a net surplus for the funded plan is based on the assumption that the net
 
assets represent a future value for
Equinor, either as a possible distribution to premium fund which can be used for future funding of new liabilities, or as disbursement of
equity in the pension fund.
The net interest related to defined benefit plans is calculated by applying the discount rate to
 
the net present value of the benefit
obligation and is presented in the Consolidated statement of income within Net financial
 
items. The difference between estimated
interest income and actual return is recognised in the Consolidated statement of comprehensive
 
income as actuarial gains/losses.
Actuarial gains and losses are recognised in full in the Consolidated statement of comprehensive income
 
in the period in which they
occur, while actuarial gains and losses related to provision for termination benefits are recognised in the Consolidated statement of
income in the period in which they occur. Due to the parent company Equinor ASA's functional currency being USD, the significant
part of Equinor's pension obligations will be payable in a foreign currency (i.e. NOK). As
 
a consequence, actuarial gains and losses
related to the parent company's pension obligations include the impact of exchange rate fluctuations.
Contributions to defined contribution schemes are recognised in the Consolidated statement of income
 
as pension costs in the period
in which the contribution amounts are earned by the employees.
Notional contribution plans, reported in the parent company Equinor ASA, are recognised as Pension
 
liabilities with the actual value of
the notional contributions and promised return at reporting date. Notional contributions are recognised
 
in the Consolidated statement
of income as periodic pension cost, while changes in fair value of the employees’ notional assets
 
are reflected in the Consolidated
statement of income under Net financial items.
Periodic pension cost is accumulated in cost pools and allocated to business areas and Equinor’s
 
operated joint operations (licences)
on an hours’ incurred basis and recognised in the Consolidated statement of income based on
 
the function of the cost.
------------------------------------------------------------------------------------------------------------------------------------
Pension plans in Equinor
The main pension plans for Equinor ASA and its most significant subsidiaries are defined contribution plans which includes certain
unfunded elements (notional contribution plans
). In addition, several employees and former employees of the Equinor Group is a
member of certain defined benefit plans. The benefit plan in Equinor ASA was closed in 2015
 
for new employees and for employees
with more than 15 years to regular retirement age.
Equinor's defined benefit plans are generally based on a minimum of 30 years of
service and 66% of the final salary level, including an assumed benefit from the Norwegian National Insurance Scheme.
 
The
Norwegian companies in the group are subject to, and complies with, the requirements of the Norwegian
 
Mandatory Company
Pensions Act.
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
121
The defined benefit plans in Norway are managed and financed through Equinor Pensjon (Equinor's
 
pension fund - hereafter Equinor
Pension). Equinor Pension is an independent pension fund that covers the employees in Equinor's
 
Norwegian companies. The
pension fund's assets are kept separate from the company's and group companies' assets. Equinor Pension
 
is supervised by the
Financial Supervisory Authority of Norway ("Finanstilsynet") and is licenced to operate as a pension fund.
Equinor has more than one defined benefit plan, but the disclosure is made in total since the plans are not subject to materially
different risks. Pension plans outside Norway are not material and as such not disclosed separately. The tables in this note present
pension costs on a gross basis before allocation to licence partners. In the Consolidated statement of income, the pension costs in
Equinor ASA are presented net of costs allocated to licence partners.
Equinor is also a member of a Norwegian national agreement-based early retirement plan (“AFP”), and the premium is calculated
based on the employees' income but limited to 7.1 times the basic amount in the National Insurance scheme (7.1 G).
 
The premium is
payable for all employees until age
62
. Pension from the AFP scheme will be paid from the AFP plan administrator
 
to employees for
their full lifetime.
Net pension cost
(in USD million)
2022
2021
2020
Notional contribution plans
57
60
55
Defined benefit plans
188
216
184
Defined contribution plans
213
213
192
Total net pension cost
458
488
432
In addition to the pension cost presented in the table above, financial items related to
 
defined benefit plans are included in the
Consolidated statement of income within Net financial items. Interest cost and changes in fair value of
 
notional contribution plans
amounts to USD
105
 
million in 2022 and USD
238
 
million in 2021. Interest income of USD
116
 
million has been recognised in 2022,
and USD
106
 
million in 2021.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
122
 
Equinor, Annual Report on Form 20-F 2022
 
Changes in pension liabilities and plan assets
 
during the year
(in USD million)
2022
2021
Pension liabilities at 1 January
9,358
9,216
Current service cost
183
208
Interest cost
105
238
Actuarial (gains)/losses and currency effects
(1,785)
(72)
Changes in notional contribution liability and other
 
effects
67
63
Benefits paid
(258)
(295)
Pension liabilities at 31 December
7,670
9,358
Fair value of plan assets at 1 January
6,404
6,234
Interest income
116
106
Return on plan assets (excluding interest income)
(622)
291
Company contributions
104
114
Benefits paid
(121)
(137)
Other effects
6
-
Foreign currency translation effects
(669)
(204)
Fair value of plan assets at 31 December
5,218
6,404
Net pension liability at 31 December
2,452
2,954
Represented by:
Asset recognised as non-current pension assets
 
(funded plan)
1,219
1,449
Liability recognised as non-current pension liabilities
 
(unfunded plans)
3,671
4,403
Pension liabilities specified by funded and unfunded
 
pension plans
7,670
9,358
Funded
3,999
4,955
Unfunded
3,671
4,403
Equinor recognised an actuarial gain from changes in financial assumptions in 2022, mainly due to a larger
 
increase in discount rate
compared to the other assumptions. An actuarial loss was recognised in 2021.
Actuarial losses and gains recognised directly
 
in Other comprehensive income (OCI)
(in USD million)
2022
2021
2020
Net actuarial (losses)/gains recognised in OCI
 
during the year
174
63
3
Foreign currency translation effects
287
84
(109)
Tax effects of actuarial (losses)/gains recognised in OCI
(105)
(35)
19
Recognised directly in OCI during the year, net of tax
356
112
(87)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
123
Actuarial assumptions
Assumptions used to determine
benefit costs in %
Assumptions used to determine
benefit obligations in %
Rounded to the nearest quartile
2022
2021
2022
2021
Discount rate
2.00
1.75
3.75
2.00
Rate of compensation increase
2.50
2.00
3.50
2.50
Expected rate of pension increase
1.75
1.25
2.75
1.75
Expected increase of social security base amount (G-amount)
2.25
2.00
3.25
2.25
Weighted-average duration of the defined benefit obligation
13.5
15.2
The assumptions presented are for the Norwegian companies in Equinor which are members of
 
Equinor's pension fund. The defined
benefit plans of other subsidiaries are immaterial to the consolidated pension assets and liabilities.
Sensitivity analysis
The table below presents an estimate of the potential effects of changes in the key assumptions for the defined benefit
 
plans. The
following estimates are based on facts and circumstances as of 31 December 2022.
Discount rate
Expected rate of
compensation
increase
Expected rate of
pension increase
Mortality assumption
(in USD million)
0.50%
-0.50%
0.50%
-0.50%
0.50%
-0.50%
+ 1 year
- 1 year
Effect on:
Defined benefit obligation at 31 December 2022
(491)
553
109
(104)
462
(422)
285
(257)
Service cost 2023
(16)
18
8
(7)
12
(11)
6
(5)
The sensitivity of the financial results to each of the key assumptions has been estimated
 
based on the assumption that all other
factors would remain unchanged. The estimated effects on the financial result would differ from those that would
 
actually appear in the
Consolidated financial statements because the Consolidated financial statements would also reflect the
 
relationship between these
assumptions.
 
 
 
 
 
 
 
 
 
 
 
124
 
Equinor, Annual Report on Form 20-F 2022
 
Pension assets
The plan assets related to the defined benefit plans were measured at fair value. Equinor Pension
 
invests in both financial assets and
real estate.
The table below presents the portfolio weighting as approved by the board of Equinor Pension
 
for 2022. The portfolio weight during a
year will depend on the risk capacity.
Target portfolio
weight
(in %)
2022
2021
Equity securities
32.9
34.1
 
29-38
Bonds
53.1
50.2
 
46-59
Money market instruments
7.4
9.1
 
0-14
Real estate
6.6
6.6
 
5-10
Total
100.0
100.0
In 2022,
44
% of the equity securities and
3
% of bonds had quoted market prices in an active market.
54
% of the equity securities,
97
% of bonds and
100
% of money market instruments had market prices based on inputs other than quoted
 
prices. If quoted market
prices are not available, fair values are determined from external calculation models based on market
 
observations from various
sources.
In 2021,
61
% of the equity securities and
3
% of bonds had quoted market prices in an active market.
37
% of the equity securities,
97
% of bonds and
100
% of money market instruments had market prices based on inputs other than quoted
 
prices.
For definition of the various levels, see note 28 Financial instruments and fair value measurement.
Estimated company contributions to be made to Equinor Pension in 2023 is approximately USD
108
 
million.
23 Provisions and other liabilities
Accounting policies
Asset retirement obligations (ARO)
Provisions for asset retirement obligations (ARO) are recognised when Equinor has an obligation
 
(legal or constructive) to dismantle
and remove a facility or an item of property, plant and equipment and to restore the site on which it is located, and when a reliable
estimate of that liability can be made. Normally an obligation arises for a new facility, such as an oil and natural gas production or
transportation facility, upon construction or installation. An obligation may also arise during the period of operation of a facility through
a change in legislation or through a decision to terminate operations or be based on commitments
 
associated with Equinor's ongoing
use of pipeline transport systems where removal obligations rest with the volume shippers.
The amount recognised is the present value of the estimated future expenditures determined in accordance
 
with local conditions and
requirements. The cost is estimated based on current regulations and technology, considering relevant risks and uncertainties. The
discount rate used in the calculation of the ARO is a market-based risk-free rate based
 
on the applicable currency and time horizon of
the underlying cash flows. The provisions are classified under Provisions in the Consolidated
 
balance sheet.
When a provision for ARO is recognised, a corresponding amount is recognised to increase the
 
related property, plant and equipment
and is subsequently depreciated as part of the property, plant and equipment. Any change in the present value of the estimated
expenditure is reflected as an adjustment to the provision and the corresponding property, plant and equipment. When a decrease in
the ARO related to a producing asset exceeds the carrying amount of the asset, the excess is
 
recognised as a reduction of
Depreciation, amortisation and net impairment losses in the Consolidated statement of income.
 
When an asset has reached the end
of its useful life, all subsequent changes to the ARO are recognised as they occur
 
in Operating expenses in the Consolidated
statement of income.
Removal provisions associated with Equinor's role as shipper of volumes through third party transport systems
 
are expensed as
incurred.
Estimation uncertainty regarding asset retirement obligations
Establishing the appropriate estimates for such obligations are based on historical knowledge combined with
 
knowledge of ongoing
technological developments, expectations about future regulatory and technological development and
 
involve the application of
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
125
judgement and an inherent risk of significant adjustments. The costs of decommissioning and
 
removal activities require revisions due
to changes in current regulations and technology while considering relevant risks and uncertainties.
 
Most of the removal activities are
many years into the future, and the removal technology and costs are constantly changing. The
 
speed of the transition to renewable
energy sources may also influence the production period, hence the timing of the removal activities.
 
The estimates include
assumptions of norms, rates and time required which can vary considerably depending on the
 
assumed removal complexity.
Moreover, changes in the discount rate and foreign currency exchange rates may impact the estimates significantly. As a result, the
initial recognition of ARO and subsequent adjustments involve the application of significant
 
judgement.
---------------------------------------------------------------------------------------------------------------------------------
(in USD million)
Asset retirement
obligations
Other
 
provisions and
liabilities,
including
claims and
litigations
Total
Non-current portion at 31 December 2021
17,279
2,620
19,899
Current portion at 31 December 2021 reported
 
as Trade, other payables and
provisions
138
1,566
1,704
Provisions and other liabilities at 31 December 2021
17,417
4,186
21,603
New or increased provisions and other liabilities
998
497
1,495
Change in estimates
(255)
1,283
1,028
Amounts charged against provisions and other liabilities
(204)
(1,830)
(2,034)
Effects of change in the discount rate
(4,920)
(212)
(5,132)
Reduction due to divestments
(361)
(181)
(542)
Accretion expenses
387
62
449
Reclassification and transfer
(46)
841
795
Foreign currency translation effects
(1,282)
(88)
(1,370)
Provisions and other liabilities at 31 December 2022
11,734
4,558
16,292
Non-current portion at 31 December 2022
11,569
4,064
15,633
Current portion at 31 December 2022 reported
 
as Trade, other payables and
provisions
165
494
659
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
126
 
Equinor, Annual Report on Form 20-F 2022
 
Equinor's estimated asset retirement obligations (ARO) have decreased by USD
5,683
 
million to USD
11,734
 
million at 31 December
2022 compared to year-end 2021, mainly due to increased discount rates and strengthening
 
of USD versus NOK. Changes in ARO
are reflected within Property, plant and equipment and Provisions and other liabilities in the Consolidated balance sheet.
In certain production sharing agreements (PSA), Equinor’s estimated share of asset retirement
 
obligation (ARO) is paid into an escrow
account over the producing life of the field. These payments are considered down-payments of the
 
liabilities and included in the line
item Amounts charged against provisions and other liabilities.
Claims and litigations mainly relate to expected payments for unresolved claims. The timing
 
and amounts of potential settlements in
respect of these claims are uncertain and dependent on various factors that are outside management's control.
 
For further information
on provisions and contingent liabilities, see note 26 Other commitments, contingent liabilities and
 
contingent assets.
 
The timing of cash outflows of asset retirement obligations depends on the expected cease of production
 
at the various facilities.
Line item Change in estimates includes USD
791
 
million related to SDFI liability. See note 27 Related parties for further details.
Line item Amounts charged against provisions and other liabilities includes settlement of USD
1,050
 
million related to Brazilian
Offshore licence BM-S-8.
Sensitivities with regards to discount rate on the total ARO portfolio
The discount rate sensitivity has been calculated by assuming a reasonably possible change of
1.2
 
percentage points.
An increase in the discount rate of
1.2
 
percentage points would reduce the ARO liability by USD
1,705
 
million. A corresponding
reduction would increase the liability by USD
2,190
 
million. See note 3 Consequences of initiatives to limit climate changes for
sensitivity with regards to change in the removal year.
Expected timing of cash outflows
(in USD million)
Asset retirement
obligations
Other
 
provisions and
liabilities, including
claims and litigations
Total
2023 - 2027
1,201
3,664
4,865
2028 - 2032
1,239
198
1,437
2033 - 2037
4,058
158
4,216
2038 - 2042
3,429
24
3,453
Thereafter
1,807
514
2,321
At 31 December 2022
11,734
4,558
16,292
24 Trade, other payables and provisions
At 31 December
(in USD million)
2022
2021
Trade payables
6,207
6,249
Non-trade payables and accrued expenses
2,688
2,181
Payables due to participation in joint operations and
 
similar arrangements
2,074
1,876
Payables to equity accounted associated companies
 
and other related parties
1,479
2,045
Total financial trade and other payables
12,449
12,350
Current portion of provisions and other non-financial
 
payables
903
1,960
Trade, other payables and provisions
13,352
14,310
Included in Current portion of provisions and other non-financial payables are certain provisions that
 
are further described in note 23
Provisions and other liabilities and in note 26 Other commitments, contingent liabilities and contingent
 
assets. For information
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
127
regarding currency sensitivities, see note 28 Financial instruments and fair value measurement. For further
 
information on payables to
equity accounted associated companies and other related parties, see note 27 Related parties.
25 Leases
Accounting policies
Leases
A lease is defined as a contract that conveys the right to control the use of an identified asset for
 
a period of time in exchange for
consideration. At the date at which the underlying asset is made available for Equinor, the present value of future lease
 
payments
(including extension options considered reasonably certain to be exercised) is recognised as a lease liability. The present value is
calculated using Equinor’s incremental borrowing rate. A corresponding right-of-use
 
(RoU) asset is recognised, including lease
payments and direct costs incurred at the commencement date. Lease payments are reflected as interest
 
expense and a reduction of
lease liabilities. The RoU assets are depreciated over the shorter of each contract’s term and the
 
assets’ useful life.
Short term leases (12 months or less) and leases of low value assets (regarded as such when
 
the sum of nominal lease payments
over the lease term do not exceed USD 500.000) are expensed or (if appropriate) capitalised as
 
incurred, depending on the activity in
which the leased asset is used.
Many of Equinor’s lease contracts, such as rig and vessel leases, involve several additional
 
services and components, including
personnel cost, maintenance, drilling related activities, and other items. For a number of these
 
contracts, the additional services
represent a not inconsiderable portion of the total contract value. Non-lease components within lease contracts
 
are accounted for
separately for all underlying classes of assets and reflected in the relevant expense category or (if
 
appropriate) capitalised as
incurred, depending on the activity involved.
Accounting judgement regarding leases
In the oil and gas industry, where activity frequently is carried out through joint arrangements or similar arrangements, the application
of IFRS 16 Leases requires evaluations of whether the joint arrangement or its operator is the
 
lessee in each lease agreement and
consequently whether such contracts should be reflected gross (100%) in the operator’s
 
financial statements, or according to each
joint operation partner’s proportionate share of the lease.
In many cases where an operator is the sole signatory to a lease contract of an asset to
 
be used in the activities of a specific joint
operation, the operator does so implicitly or explicitly on behalf of the joint arrangement. In certain jurisdictions,
 
and importantly for
Equinor as this includes the Norwegian continental shelf (NCS), the concessions granted by the
 
authorities establish both a right and
an obligation for the operator to enter into necessary agreements in the name of the joint operations
 
(licences).
As is the customary norm in upstream activities operated through joint arrangements, the operator
 
will manage the lease, pay the
lessor, and subsequently re-bill the partners for their share of the lease costs. In each such instance, it is necessary to determine
whether the operator is the sole lessee in the external lease arrangement, and if
 
so, whether the billings to partners may represent
sub-leases, or whether it is in fact the joint arrangement which is the lessee, with each
 
participant accounting for its proportionate
share of the lease. Where all partners in a licence are considered to share the primary responsibility for lease
 
payments under a
contract, Equinor’s proportionate share of the related lease liability and RoU asset will
 
be recognised net by Equinor. When Equinor is
considered to have the primary responsibility for the full external lease payments, the lease liability is recognised
 
gross (100%).
Equinor derecognises a portion of the RoU asset equal to the non-operator’s
 
interests in the lease, and replace it with a corresponding
financial lease receivable, if a financial sublease is considered to exist between Equinor and the licence.
 
A financial sublease will
typically exist where Equinor enters into a contract in its own name, has the primary responsibility for
 
the external lease payments, the
underlying asset will only be used on one specific licence, and the costs and risks related to the
 
use of the asset are carried by that
specific licence. Depending on facts and circumstances in each case, the conclusions reached
 
may vary between contracts and legal
jurisdictions.
--------------------------------------------------------------------------------------------------------------------------------
Equinor leases certain assets, notably drilling rigs, transportation vessels, storages and office facilities for operational activities.
Equinor is mostly a lessee, and the use of leases serves operational purposes rather than
 
as a tool for financing.
Information related to lease payments and lease
 
liabilities
(in USD million)
2022
2021
Lease liabilities at 1 January
3,562
4,406
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
128
 
Equinor, Annual Report on Form 20-F 2022
 
New leases, including remeasurements and cancellations
1,644
476
Gross lease payments
(1,484)
(1,350)
Lease interest
95
91
Lease repayments
 
(1,389)
(1,389)
(1,259)
(1,259)
Foreign currency translation effects
(149)
(61)
Lease liabilities at 31 December
3,667
3,562
Current lease liabilities
1,258
1,113
Non-current lease liabilities
2,409
2,449
Lease expenses not included in lease liabilities
(in USD million)
2022
2021
Short-term lease expenses
286
160
Payments related to short term leases are mainly related to drilling rigs and transportation
 
vessels, for which a significant portion of
the lease costs have been included in the cost of other assets, such as rigs used
 
in exploration or development activities. Variable
lease expense and lease expense related to leases of low value assets are not significant.
Equinor recognised revenues of USD
319
 
million in 2022 and USD
272
 
million in 2021 related to lease costs recovered from licence
partners related to lease contracts being recognised gross by Equinor.
Commitments relating to lease contracts which had not yet commenced at year-end are included
 
within Other commitments in note
 
26 Other commitments, contingent liabilities and contingent assets.
A maturity profile based on undiscounted contractual cash flows for lease liabilities is disclosed
 
in note 4 Financial risk and capital
management.
Non-current lease liabilities maturity profile
At 31 December
(in USD million)
2022
2021
Year 2 and 3
1,360
1,164
Year 4 and 5
483
586
After 5 years
566
699
Total repayment of non-current lease liabilities
2,409
2,449
The Right of use assets are included within the line item Property, plant and equipment in the Consolidated balance sheet. See also
note 12 Property, plant and equipment.
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
129
26 Other commitments, contingent liabilities and contingent
 
assets
Accounting policies
Estimation uncertainty regarding levies
Equinor’s global business activities are subject to different indirect taxes in various jurisdictions around the world. In these
jurisdictions, governments can respond to global or local development, including climate related matters and public fiscal
balances, by issuing new laws or other regulations stipulating changes in value added tax, tax on emissions, customs duties or
other levies which may affect profitability and even the viability of Equinor’s business in that jurisdiction. Equinor mitigates this
risk by using local legal representatives and staying up to date with the legislation in the jurisdictions where activities are
carried out. Occasionally, legal disputes arise from difference in interpretations. Equinor’s legal department, together with local
legal representatives, estimate the outcome from such legal disputes based on first-hand knowledge. Such estimates may
differ from the actual results.
--------------------------------------------------------------------------------------------------------------------------------
Contractual commitments
Equinor had contractual commitments of USD
5,454
 
million as of 31 December 2022. The contractual commitments reflect Equinor's
proportional share and mainly comprise construction and acquisition of property, plant and equipment as well as committed
investments/funding or resources in equity accounted entities. It also includes Equinors’ estimated
 
expenditures related to
commitments to drill a certain number of wells, commitments which sometimes can be a prerequisite to be awarded oil and
 
gas
exploration and production licences.
At the end of 2022, Equinor was committed to participate in
40
 
wells, with an average ownership interest of approximately
42
%.
Equinor's share of estimated expenditures to drill these wells amounts to USD
566
 
million. Additional wells that Equinor may become
committed to participating in depending on future discoveries in certain licences are not included in
 
these numbers.
Other long-term commitments
Equinor has entered into various long-term agreements for pipeline transportation as well as terminal
 
use, processing, storage and
entry/exit capacity commitments and commitments related to specific purchase agreements. The
 
agreements ensure the rights to the
capacity or volumes in question, but also impose on Equinor the obligation to pay for the agreed-upon
 
service or commodity,
irrespective of actual use. The contracts' terms vary, with durations of up to
2060
.
Take-or-pay contracts for the purchase of commodity quantities are only included in the table below if their contractually agreed
pricing is of a nature that will or may deviate from the obtainable market prices for the
 
commodity at the time of delivery.
Obligations payable by Equinor to entities accounted for in the Equinor group using the equity method
 
are included in the table below
with Equinor’s full proportionate share. For
 
assets (such as pipelines) that are included in the Equinor accounts through joint
operations or similar arrangements, and where consequently Equinor’s share of
 
assets, liabilities, income and expenses (capacity
costs) are reflected on a line-by-line basis in the Consolidated financial statements, the amounts in the table include
 
the net
commitment payable by Equinor (i.e. Equinor’s proportionate share of the
 
commitment less Equinor's ownership share in the
applicable entity).
The table below also includes USD
3,033
 
million as the non-lease components of lease agreements reflected in the accounts
according to IFRS 16, as well as leases not yet commenced. For commenced leases, please refer to
 
note 25 Leases.
Nominal minimum other long-term commitments at 31 December 2022:
(in USD million)
2023
2,603
2024
2,103
2025
1,892
2026
1,260
2027
1,309
Thereafter
5,733
Total other long-term commitments
14,900
130
 
Equinor, Annual Report on Form 20-F 2022
 
Guarantees
Equinor has guaranteed for its proportionate share of some of our associates’
 
long-term bank debt, payment obligations under
contracts, and certain third-party obligations. The total amount guaranteed at year-end 2022 is USD
1,725
 
million. The book value of
the guarantees is immaterial.
Contingent liabilities and contingent assets
Agbami dispute settlement agreement and licence extension
During 2022, an agreement was reached in a three-year long negotiation between the parties
 
Nigerian National Petroleum Company
Limited (NNPC), Chevron and Equinor. The parties have agreed to an extension of the operating licence period and the related
Production Sharing Contract (PSC) for Oil Mining Lease (OML) 128 of the unitised Agbami field
 
until 2042. At the same time, the
parties agreed outstanding legal disputes related to the allocation between the parties of cost
 
oil, tax oil and profit oil volumes. The
settlement agreement awards Equinor with an amicable compensation for overlifted volumes, which will
 
be payable over the 20-year
licence extension. The amounts and timing of payments to be received depend on a number of factors
 
related to operation of the field,
as well as future oil prices and production volumes. Equinor will consequently recognise settlement
 
payments when received, and no
amounts have been recognised in the Consolidated statement of income or Balance sheet for 2022.
 
The parties are currently
undertaking necessary legal actions in order to formally close the legal disputes.
Claim from Petrofac regarding multiple variation order requests performed in Algeria (In Salah)
Petrofac International (UAE) LLC (“PIUL”) was awarded the EPC Contract to execute
 
the ISSF Project (the In Salah Southern Fields
Project which has finalised the development of 4 gas fields in central Algeria). Following suspension
 
of activity after the terrorist attack
at another gas field in Algeria (In Amenas) in 2013, PIUL issued multiple Variation Order Requests (“VoRs”) related to the costs
incurred for stand-by and remobilization costs after the evacuation of expatriates. Several VoRs have been paid, but the settlement of
the remaining has been unsuccessful. PIUL initiated arbitration in August 2020 claiming an estimated amount of USD
533
 
million, of
which Equinor holds a
31.85
% share. Equinor's maximum exposure amounts to USD
163
 
million. Equinor has provided for its best
estimate in the matter.
Withholding tax dispute regarding remittances from Brazil to Norway
Remittances made from Brazil for services are normally subject to withholding income tax.
 
In 2012, Equinor’s subsidiaries in Brazil
filed a lawsuit to avoid paying this tax on remittances made to Equinor ASA and Equinor Energy
 
AS for services without transfer of
technology based on the Double Tax Treaty Brazil has with Norway.
 
Court proceedings through several levels in the legal system
have been ongoing since a first level decision in Equinor’s favour was
 
reached in 2013, and a final verdict has not yet been reached.
Withholding tax has not been paid since 2014.
 
Equinor's maximum exposure is estimated at approximately USD
146
 
million. Equinor
is of the view that all applicable tax regulations have been applied in the case and that Equinor
 
has a strong position. No amounts
have consequently been provided for in the financial statements.
Suit for an annulment of Petrobras’ sale of the interest in BM-S-8 to Equinor
In March 2017, an individual connected to the Union of Oil Workers of Sergipe (Sindipetro) filed a class action
 
suit against Petrobras,
Equinor, and ANP - the Brazilian Regulatory Agency - to seek annulment of Petrobras’ sale of the interest and operatorship in BM-S-8
to Equinor, which was closed in November 2016 after approval by the partners and authorities. In February 2022, sentence in the
annulment case was issued at the first instance level, and Equinor won on all merits. The
 
case was appealed by the plaintiff and
Equinor has filed counter arguments. At the end of 2022, the acquired interest remains in Equinor’s
 
balance sheet, where the assets
related to phase 1 have been reclassified to property, plant and equipment and the assets related to phase 2 are presented as
intangible assets, all of which are part of the Exploration & Production International (E&P International)
 
segment.
Brazilian law creating uncertainty regarding certain tax incentives
Equinor is currently part in two legal matters in the state of Rio de Janeiro in Brazil
 
related to a law requiring taxpayers that benefits
from ICMS tax incentives (i.e. Repetro) to deposit
10
% of the savings made from such benefits into a state fund. Equinor
 
is of the
opinion that specific incentives so far relevant for the Roncador and Peregrino fields are not
 
in scope of the law, while the state of Rio
de Janeiro requires deposits to be paid with the addition of fines and interests. Several legal
 
actions to oppose the laws and related
payments have therefore been initiated by both Equinor’s peers and the Brazilian
 
Petroleum and Gas Institute (IBP). At year-end
2022, the maximum exposure for Equinor in these various matters has been estimated to a
 
total of USD
132
 
million. Equinor is of the
opinion that the law is unconstitutional, especially for Repetro incentives, and this
 
will be upheld in future legal proceedings. No
amounts have consequently been provided for in the financial statements.
KKD oil sands partnership
Canadian tax authorities have issued a notice of reassessment for 2014 for Equinor's Canadian
 
subsidiary which was party to
Equinor's divestment of
40
% of the KKD Oil Sands partnership at that time. The reassessment,
 
which has been appealed, adjusts the
allocation of the proceeds of disposition of certain Canadian resource properties from the partnership. Maximum
 
exposure is
estimated to be approximately USD
372
 
million. The appeal process with the Canadian tax authorities, as well as any subsequent
litigation that may become necessary, may take several years. No taxes will become payable until the matter has been finally settled.
Equinor, Annual Report on Form 20-F 2022
 
131
Equinor is of the view that all applicable tax regulations have been applied in the
 
case and that Equinor has a strong position. No
amounts have consequently been provided for in the financial statements.
Resolved dispute with Norwegian tax authorities related to Equinor Service Center Belgium
 
N.V
In the fourth quarter of 2020, Equinor received a decision from the Norwegian tax authorities
 
related to the capital structure of the
subsidiary Equinor Service Center Belgium N.V., concluding that the capital structure had to be based on the arm length’s principle,
affecting the fiscal years 2012 to 2016. Equinor received a claim of USD
182
 
million that was paid in 2021. During 2022, the tax
authorities reversed their decision and accepted Equinor’s initial position. The tax payment
 
has been reimbursed to Equinor, adjusted
for changes in tax rates. The adjustment, which has been recognised as tax expense in the Consolidated
 
statement of income in
2022, is considered immaterial.
Dispute with Norwegian tax authorities regarding R&D costs in the offshore tax regime
Equinor has an ongoing dispute regarding the level of Research & Development cost to be allocated
 
to the offshore tax regime.
During 2022, the Oil Taxation Office (OTO) informed Equinor that it had decided to accept Equinor’s position regarding certain
disputed items, resulting in a reduction in Equinor’s maximum exposure. Further, Equinor has accepted an increase in taxable
 
income
for both onshore and offshore tax. A previously recognised provision of USD
95
 
million has been reclassified to current tax payable.
Equinor’s Income tax expense was not affected by this development, and the remaining expected
 
maximum exposure related to R&D
costs in the offshore tax regime is considered immaterial.
Dispute with Norwegian tax authorities regarding internal pricing of natural gas liquids
The Oil Taxation Office has challenged the internal pricing of certain products of natural gas liquids sold from Equinor Energy AS to
Equinor ASA in the years 2011-2020. During 2022 there has been development in various elements of these cases, where parts of
the previous exposure have been resolved or have reached the end of available appeal processes,
 
and other parts have been
appealed. Following these developments, which did not impact the Consolidated statement of income
 
significantly, the maximum
exposure regarding the gas liquid pricing remains at an estimated USD
71
 
million. Equinor has provided for its best estimate in the
matter.
Other claims
During the normal course of its business, Equinor is involved in legal proceedings, and several other unresolved
 
claims are currently
outstanding. The ultimate liability or asset, in respect of such litigation and claims cannot
 
be determined at this time. Equinor has
provided in its Consolidated financial statements for probable liabilities related to litigation and
 
claims based on its best estimate.
Equinor does not expect that its financial position, results of operations or cash flows will be materially
 
affected by the resolution of
these legal proceedings. Equinor is actively pursuing the above disputes through the contractual
 
and legal means available in each
case, but the timing of the ultimate resolutions and related cash flows, if any, cannot at present be determined with sufficient reliability.
Provisions related to claims other than those related to income tax are reflected within note
 
23 Provisions and other liabilities.
Uncertain income tax related liabilities are reflected as current tax payables or deferred tax
 
liabilities as appropriate, while uncertain
tax assets are reflected as current or deferred tax assets.
132
 
Equinor, Annual Report on Form 20-F 2022
 
27 Related parties
Transactions with the Norwegian State
The Norwegian State is the majority shareholder of Equinor and also holds major
 
investments in other Norwegian companies. As of
 
31 December 2022, the Norwegian State had an ownership interest in Equinor of
67.0
% (excluding Folketrygdfondet, the Norwegian
national insurance fund, of
3.4
%). This ownership structure means that Equinor participates in transactions
 
with many parties that are
under a common ownership structure and therefore meet the definition of a related party. The responsibility for the Norwegian State`s
shareholding in Equinor was transferred from the Ministry of Petroleum and Energy to the Ministry
 
of Trade and Industry on 1 January
2022.
Total purchases of oil and natural gas liquids from the Norwegian State amounted to USD
12,617
 
million, USD
9,572
 
million and USD
5,108
 
million in 2022, 2021 and 2020, respectively. These purchases of oil and natural gas liquids are recorded in Equinor ASA. In
addition, Equinor ASA sells in its own name, but for the Norwegian State’s account and risk, the
 
Norwegian State’s gas production.
These transactions are presented net. For further information please see note 7 Total revenues and other income. The most
significant items included in the line-item Payables to equity accounted associated companies and
 
other related parties in note 24
Trade and other payables, are amounts payable to the Norwegian State for these purchases.
The line-item Prepayments and Financial Receivables includes USD
1,461
 
million which represent a gross receivable from the
Norwegian state under the Marketing Instruction in relation to the state’s (SDFI) expected participation in the gas
 
sales activities of a
foreign subsidiary of Equinor. At year end 2021 the corresponding amount was USD
435
 
million. The increase is mainly related to
increased volumes and higher cost price on the gas storage. A corresponding non-current liability
 
of USD
1,461
 
million has been
recognized, representing SDFI's estimated interest in the gas sales activities in the foreign
 
subsidiary.
Other transactions
In its ordinary business operations Equinor enters into contracts such as pipeline transport, gas storage
 
and processing of petroleum
products, with companies in which Equinor has ownership interests. Such transactions are
 
included within the applicable captions in
the Consolidated statement of income. Gassled and certain other infrastructure assets are
 
operated by Gassco AS, which is an entity
under common control by the Norwegian Ministry of Petroleum and Energy. Gassco’s activities are performed on behalf of and for the
risk and reward of pipeline and terminal owners, and capacity payments flow through Gassco to the respective
 
owners. Equinor
payments that flowed through Gassco in this respect amounted to USD
1,210
 
million, USD
1,030
 
million and USD
896
 
million in 2022,
2021 and 2020, respectively. These payments are mainly recorded in Equinor ASA. The stated amounts represent Equinor’s capacity
payment net of Equinor’s own ownership interests in Gassco operated infrastructure.
 
In addition, Equinor ASA manages, in its own
name, but for the Norwegian State’s account and risk, the Norwegian State’s share of the Gassco costs. These transactions
 
are
presented net. Equinor has had transactions with other associated companies and joint ventures
 
in the course of its ordinary
business, for which amounts have not been disclosed due to materiality. In addition, Equinor has had transactions with joint
operations and similar arrangements where Equinor is operator. Indirect operating expenses incurred as operator are charged to the
joint operation or similar arrangement based on the “no-gain/no-loss” principle.
Related party transactions with management are presented in note 8 Salaries and personnel
 
expenses
.
Equinor, Annual Report on Form 20-F 2022
 
133
28 Financial instruments and fair value measurement
Accounting policies
Financial assets
Financial assets are initially recognised at fair value when Equinor becomes a party to the contractual provisions
 
of the asset. The
subsequent measurement of the financial assets depends on which category they have been
 
classified into at inception: Financial
investments at amortised cost, at fair value through profit or loss, and at fair value through
 
other comprehensive income. The
classification is based on an evaluation of the contractual terms and the business model
 
applied.
Short-term highly liquid investments with original maturity exceeding 3 months are classified as
 
current financial investments. Current
financial investments are primarily accounted for at amortised cost but also at fair value through profit or loss,
 
depending on
classification.
Trade receivables are carried at the original invoice amount less a provision for doubtful receivables which represent expected losses
computed on a probability-weighted basis.
A part of Equinor's financial investments is managed together as an investment portfolio
 
of Equinor's captive insurance company and
is held in order to comply with specific regulations for capital retention. The investment portfolio
 
is managed and evaluated on a fair
value basis in accordance with an investment strategy and is accounted for at fair value through profit or loss.
Financial assets are presented as current if they contractually will expire or otherwise are expected
 
to be recovered within 12 months
after the balance sheet date, or if they are held for the purpose of being traded. Financial
 
assets and financial liabilities are shown
separately in the Consolidated balance sheet, unless Equinor has both a legal right and a demonstrable
 
intention to net settle certain
balances payable to and receivable from the same counterparty.
Financial assets are derecognised when rights to cash flows and risks and rewards
 
of ownership are transferred through a sales
transaction or the contractual rights to the cash flows expire, are redeemed, or cancelled. Gains
 
and losses arising on the sale,
settlement or cancellation of financial assets are recognised within Net financial items.
Financial liabilities
Financial liabilities are initially recognised at fair value when Equinor becomes a party to
 
the contractual provisions of the liability. The
subsequent measurement of financial liabilities is either as financial liabilities at fair value through
 
profit or loss or financial liabilities
measured at amortised cost using the effective interest method, depending on classification. The latter
 
applies to Equinor's non-
current bank loans and bonds.
Financial liabilities are presented as current if the liability is expected to be settled as
 
part of Equinor’s normal operating cycle, the
liability is due to be settled within 12 months after the balance sheet date, Equinor does
 
not have the right to defer settlement of the
liability more than 12 months after the balance sheet date, or if the liabilities are held for the
 
purpose of being traded.
Financial liabilities are derecognised when the contractual obligations are settled, or if they expire,
 
are discharged or cancelled. Gains
and losses arising on the repurchase, settlement or cancellation of liabilities are recognised within Net
 
financial items.
Derivative financial instruments
Equinor uses derivative financial instruments to manage certain exposures to fluctuations in foreign
 
currency exchange rates, interest
rates and commodity prices. Such derivative financial instruments are initially recognised at
 
fair value on the date on which a
derivative contract is entered into and are subsequently remeasured at fair value through profit
 
and loss. The impact of commodity-
based derivative financial instruments is recognised in the Consolidated statement of income as
 
Other revenues, as such derivative
instruments are related to sales contracts or revenue-related risk management for all significant purposes. The impact
 
of other
derivative financial instruments is reflected under Net financial items.
Derivatives are carried as assets when the fair value is positive and as liabilities when
 
the fair value is negative. Derivative assets or
liabilities expected to be settled, or with the legal right to be settled more than 12 months after
 
the balance sheet date, are classified
as non-current. Derivative financial instruments held for the purpose of being traded are however
 
always classified as current.
Contracts to buy or sell a non-financial item that can be settled net in cash or another
 
financial instrument are accounted for as
financial instruments. However, contracts that are entered into and continue to be held for the purpose of the receipt or delivery of a
non-financial item in accordance with Equinor's expected purchase, sale or usage requirements,
 
also referred to as own-use, are not
accounted for as financial instruments. Such sales and purchases of physical commodity
 
volumes are reflected in the Consolidated
statement of income as Revenue from contracts with customers and Purchases [net of inventory
 
variation], respectively. This is
applicable to a significant number of contracts for the purchase or sale of crude oil and natural gas,
 
which are recognised upon
delivery.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
134
 
Equinor, Annual Report on Form 20-F 2022
 
For contracts to sell a non-financial item that can be settled net in cash, but which ultimately
 
are physically settled despite not
qualifying as own use prior to settlement, the changes in fair value are included in Gain/loss on
 
commodity derivatives (part of Other
revenues, see note 7 Total revenues and other income). When these derivatives are physically settled, the previously recognised
unrealised gain/loss is included in Physically settled commodity derivatives (also part of Other revenues).
 
The physical deliveries
made through such contracts are included in Revenue from contracts with customers at
 
contract price.
Derivatives embedded in host contracts which are not financial assets within the scope
 
of IFRS 9 are recognised as separate
derivatives and are reflected at fair value with subsequent changes through profit and
 
loss, when their risks and economic
characteristics are not closely related to those of the host contracts, and the host contracts are not
 
carried at fair value. Where there is
an active market for a commodity or other non-financial item referenced in a purchase or sale contract, a
 
pricing formula will, for
instance, be considered to be closely related to the host purchase or sales contract
 
if the price formula is based on the active market
in question. A price formula with indexation to other markets or products will however result in
 
the recognition of a separate derivative.
Where there is no active market for the commodity or other non-financial item in question, Equinor
 
assesses the characteristics of
such a price related embedded derivative to be closely related to the host contract if the price formula
 
is based on relevant indexations
commonly used by other market participants. This applies to certain long-term natural gas sales
 
agreements.
--------------------------------------------------------------------------------------------------------------------------------------
Financial instruments by category
The following tables present Equinor's classes of financial instruments and their carrying amounts by the categories
 
as they are
defined in IFRS 9 Financial Instruments. For financial investments, the difference between measurement as
 
defined by IFRS 9
categories and measurement at fair value is immaterial. For trade and other receivables
 
and payables, and cash and cash
equivalents, the carrying amounts are considered a reasonable approximation of fair value. See note 21 Finance
debt for fair value
information of non-current bonds and bank loans.
At 31 December 2022
Fair value
through profit
or loss
Non-financial
assets
Total carrying
amount
(in USD million)
Note
Amortised cost
Assets
Non-current derivative financial instruments
 
691
691
Non-current financial investments
16
117
2,616
2,733
Prepayments and financial receivables
16
1,658
404
2,063
Trade and other receivables
18
21,611
841
22,452
Current derivative financial instruments
 
4,039
4,039
Current financial investments
16
29,577
300
29,876
Cash and cash equivalents
19
12,473
3,106
15,579
Total
 
65,436
10,752
1,245
77,433
At 31 December 2021
Fair value
through profit
or loss
Non-financial
assets
Total carrying
amount
(in USD million)
Note
Amortised cost
Assets
Non-current derivative financial instruments
 
1,265
1,265
Non-current financial investments
16
253
3,093
3,346
Prepayments and financial receivables
16
707
380
1,087
Trade and other receivables
18
17,192
736
17,927
Current derivative financial instruments
 
5,131
5,131
Current financial investments
16
20,946
300
21,246
Cash and cash equivalents
19
11,412
2,714
14,126
Total
 
50,510
12,503
1,116
64,128
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
135
At 31 December 2022
Amortised
cost
Fair value
through
profit or loss
Non-financial
liabilities
Total
carrying
amount
(in USD million)
Note
Liabilities
Non-current finance debt
21
24,141
24,141
Non-current derivative financial instruments
 
2,376
2,376
Trade, other payables and provisions
24
12,449
903
13,352
Current finance debt
21
4,359
4,359
Dividend payable
2,808
2,808
Current derivative financial instruments
 
4,106
4,106
Total
 
43,757
6,482
903
51,142
At 31 December 2021
Amortised
cost
Fair value
through
profit or loss
Non-financial
liabilities
Total
carrying
amount
(in USD million)
Note
Liabilities
Non-current finance debt
21
27,404
27,404
Non-current derivative financial instruments
 
767
767
Trade, other payables and provisions
24
12,350
1,960
14,310
Current finance debt
21
5,273
5,273
Dividend payable
582
582
Current derivative financial instruments
 
4,609
4,609
Total
 
45,609
5,376
1,960
52,945
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
136
 
Equinor, Annual Report on Form 20-F 2022
 
Measurement of fair values
Quoted prices in active markets represent the best evidence of fair value and are used by Equinor
 
in determining the fair values of
assets and liabilities to the extent possible. Financial instruments quoted in active markets will
 
typically include financial instruments
with quoted market prices obtained from the relevant exchanges or clearing houses. The fair
 
values of quoted financial assets,
financial liabilities and derivative instruments are determined by reference to mid-market prices, at the
 
close of business on the
balance sheet date.
Where there is no active market, fair value is determined using valuation techniques. These include
 
using recent arm's-length market
transactions, reference to other instruments that are substantially the same, discounted cash flow
 
analysis, and pricing models and
related internal assumptions. In the valuation techniques, Equinor also takes into consideration the
 
counterparty and its own credit
risk. This is either reflected in the discount rate used or through direct adjustments to the calculated
 
cash flows. Consequently, where
Equinor reflects elements of long-term physical delivery commodity contracts at fair value, such fair value estimates to
 
the extent
possible are based on quoted forward prices in the market and underlying indexes in
 
the contracts, as well as assumptions of forward
prices and margins where observable market prices are not available. Similarly, the fair values of interest and currency swaps are
estimated based on relevant quotes from active markets, quotes of comparable instruments, and
 
other appropriate valuation
techniques.
Fair value hierarchy
The following table summarises each class of financial instruments which are recognised in the
 
Consolidated balance sheet at fair
value, split by Equinor's basis for fair value measurement.
(in USD million)
Non-current
financial
investments
Non-current
derivative
financial
instruments
- assets
Current
financial
investments
Current
derivative
financial
instruments
- assets
Cash
equivalents
Non-current
derivative
financial
instruments
- liabilities
Current
derivative
financial
instruments
- liabilities
Net fair
value
At 31 December 2022
Level 1
903
0
-
25
0
(60)
868
Level 2
1,222
97
300
3,722
3,106
(2,352)
(3,952)
2,143
Level 3
491
594
292
(24)
(94)
1,259
Total fair value
2,616
691
300
4,039
3,106
(2,376)
(4,106)
4,270
At 31 December 2021
Level 1
860
-
-
949
-
(69)
1,740
Level 2
1,840
884
300
4,108
2,714
(762)
(4,539)
4,545
Level 3
393
380
74
(4)
843
Total fair value
3,093
1,265
300
5,131
2,714
(767)
(4,609)
7,127
Level 1, fair value based on prices quoted in an active market for identical assets or liabilities,
 
includes financial instruments actively
traded and for which the values recognised in the Consolidated balance sheet are determined
 
based on observable prices on identical
instruments. For Equinor this category will, in most cases, only be relevant for investments in
 
listed equity securities and government
bonds.
Level 2, fair value based on inputs other than quoted prices included within level 1, which are derived
 
from observable market
transactions, includes Equinor's non-standardised contracts for which fair values are determined on the basis
 
of price inputs from
observable market transactions. This will typically be when Equinor uses forward prices
 
on crude oil, natural gas, interest rates and
foreign currency exchange rates as inputs to the valuation models to determine the fair value
 
of it derivative financial instruments.
Level 3, fair value based on unobservable inputs, includes financial instruments for which fair values are
 
determined on the basis of
input and assumptions that are not from observable market transactions. The fair
 
values presented in this category are mainly based
on internal assumptions. The internal assumptions are only used in the absence of quoted prices
 
from an active market or other
observable price inputs for the financial instruments subject to the valuation.
The fair value of certain earn-out agreements and embedded derivative contracts are determined
 
by the use of valuation techniques
with price inputs from observable market transactions as well as internally generated price assumptions
 
and volume profiles. The
discount rate used in the valuation is a risk-free rate based on the applicable currency and time horizon
 
of the underlying cash flows
adjusted for a credit premium to reflect either Equinor's credit premium, if the value is a liability, or an estimated counterparty credit
Equinor, Annual Report on Form 20-F 2022
 
137
premium if the value is an asset. In addition, a risk premium for risk elements not adjusted for
 
in the cash flow may be included when
applicable. The fair values of these derivative financial instruments have been classified in their
 
entirety in the third category within
current derivative financial instruments and non-current derivative financial instruments. Another reasonable
 
assumption, that could
have been applied when determining the fair value of these contracts, would be to extrapolate the
 
last observable forward prices with
inflation. If Equinor had applied this assumption, the fair value of the contracts included would
 
have increased by approximately USD
0.5
 
billion at end of 2022, while at end of 2021 the increase in fair value was approximately
 
USD
0.4
 
billion.
The reconciliation of the changes in fair value during 2022 and 2021 for financial instruments classified
 
as level 3 in the hierarchy is
presented in the following table.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
138
 
Equinor, Annual Report on Form 20-F 2022
 
(in USD million)
Non-current
financial
investments
Non-current
derivative
financial
instruments -
assets
Current
derivative
financial
instruments -
assets
Non-current
derivative
financial
instruments -
liabilities
Current
derivative
financial
instruments -
liabilities
Total amount
Opening at 1 January 2022
393
380
74
(4)
0
843
Total gains and losses recognised in statement of income
(50)
243
197
(20)
0
370
Purchases
175
10
(120)
65
Sales
-
-
2
-
22
24
Settlement
(7)
(64)
(71)
Transfer into level 3
-
80
5
85
Foreign currency translation effects
(19)
(30)
(7)
(1)
(57)
Closing at 31 December 2022
492
593
292
(24)
(94)
1,259
Opening at 1 January 2021
308
330
24
(5)
-
657
Total gains and losses recognised in statement of income
(23)
58
72
1
-
108
Purchases
119
119
Settlement
(7)
(20)
(27)
Transfer out of level 3
-
-
Foreign currency translation effects
(3)
(8)
(2)
(13)
Closing at 31 December 2021
393
380
74
(4)
-
843
During 2022 the financial instruments within level 3 have had a net increase in fair value of USD
416
 
million. The USD
370
 
million
recognised in the Consolidated statement of income during 2022 are mainly related to changes
 
in fair value of certain embedded
derivatives and earn-out agreements.
29 Subsequent events
Agreement to acquire Suncor Energy UK Limited
On 3 March 2023, Equinor entered into an agreement to acquire
100
% of Suncor Energy UK Limited for a total consideration of USD
850
 
million before adjustments for working capital and net cash. USD
250
 
million is contingent on final investment decision on the
Rosebank field. The transaction includes a non-operated interest in the producing Buzzard oil field (
29.89
%) and an additional interest
in the operated Rosebank development (
40
%). Closing of the transaction is expected in the first half of 2023 subject to relevant
regulatory approvals and will be recognised in the E&P International segment.
exhibit1p1i0
ARTICLES
 
OF
ASSOCIATION
for
Equinor ASA
(Effective
 
from
 
11
 
May
 
2022)
Article
 
1
The company's
 
name
 
is Equinor
 
ASA. The
 
company
 
is a
 
public
 
limited company.
The objective
 
of Equinor
 
ASA is to
 
develop, produce
 
and market various
 
forms of energy
 
and
derived products
 
and services, as
 
well as other
 
business. The activities
 
may also be
 
carried out
through
 
participation
 
in or cooperation
 
with other companies.
Article
 
2
The company's
 
registered
 
office
 
is located
 
in
 
the
 
municipality
 
of
 
Stavanger.
Article
 
3
The share capital
 
of the company
is
NOK 7,938,675,397.50
 
divided
into
3,175,470,159
shares of
 
NOK 2.50
 
each.
Article 4
The board of
 
directors
 
of the company
 
shall consist
 
of 9-11
 
members. The
 
board
 
of directors,
including the
 
chair and the
 
deputy chair,
 
shall be elected
 
by the
 
corporate
 
assembly.
 
Deputy
directors may be
 
elected in respect
 
of the directors
 
elected by and
 
among the employees
 
in
accordance
 
with regulations
 
stipulated in
 
or pursuant to
 
the Public Limited
 
Companies Act. The
board of directors
 
may be elected
 
for
 
up to
 
two
 
years.
Article 5
The chair
 
of the
 
board
 
alone,
 
the
 
chief
 
executive
 
officer
 
alone
 
or
 
any
 
two
 
directors
 
jointly
 
may
sign for
 
the
 
company.
 
The board may
 
grant powers of
 
procuration.
Page 1 of 3
exhibit1p2i0
Security Classification: Open
-
Status: Final
Page 2 of 3
Article
 
6
The
 
board
 
shall appoint
 
the
 
company's
 
chief
 
executive
 
officer
 
and
 
stipulate
 
his/her
 
salary.
Article
 
7
The company shall
 
have a corporate
 
assembly
 
consisting
 
of 18 members
 
and deputy
 
members.
The annual
 
general
 
meeting
 
shall
 
elect
 
12
 
members
 
and
 
four
 
deputy
 
members
 
for
 
these
 
12
members. Six
 
members
 
and deputies for
 
these
 
six
 
members
 
shall be elected
 
by and among
 
the
employees
 
of the
 
company
 
in
 
accordance
 
with
 
regulations
 
stipulated
 
in or pursuant
 
to
 
the
 
Public
Limited Companies
 
Act.
The corporate assembly
 
shall elect a
 
chair and deputy
 
chair from and
 
among its
 
members. The
corporate assembly
 
shall hold at
 
least 2 meetings
 
annually.
Article
 
8
The annual general
 
meeting shall be
 
held each year
 
by the end
 
of June. Annual
 
general
meetings shall
 
be held in the
 
municipality
 
of Stavanger
 
or Oslo.
Article
9
Documents
 
relating
 
to
 
matters
 
to
 
be dealt
 
with
 
by the company's
 
annual
 
general
 
meeting,
including documents
 
which
 
by
 
law
 
shall
 
be included
 
in
 
or
 
attached
 
to
 
the
 
notice
 
of
 
the
 
annual
general meeting,
 
do not
 
need to
 
be sent to
 
the
 
shareholders
 
if
 
the
 
documents
 
are accessible
 
on
the company's home
 
pages. A shareholder
 
may nevertheless
 
request that documents,
 
which relate
to matters
 
to
 
be
 
dealt
 
with
 
by
 
the
 
company's
 
annual
 
general
 
meeting,
 
be
 
sent
 
to
 
him/her.
The annual
 
general
 
meeting
 
shall address
 
and decide
 
the
 
following
 
matters:
1.
 
Adoption of the annual report and accounts, including
 
the declaration of dividends.
2.
 
Any other matters which
 
are referred to
 
the annual general meeting by statute law or
the articles
 
of association.
Shareholders
 
are able
 
to
 
vote in
 
writing,
 
including
 
through
 
electronic
 
communication,
 
in a
period
 
before the general
 
meeting. The board
 
of directors can
 
stipulate guidelines
 
for such
advance
 
voting.
 
It
 
must be
 
stated in
 
the notice
 
for the
 
general
 
meeting
 
which guidelines
 
have
been set.
Article
10
The company
 
shall be responsible
 
for
 
the
 
marketing and
 
sale of the
 
state's petroleum
 
which is
produced
 
from the
 
state's
 
direct
 
financial
 
interest
 
(SDFI)
 
on
 
the
 
Norwegian
 
continental
 
shelf,
 
as
well as
 
for
 
the
 
marketing
 
and
 
sale
 
of
 
petroleum
 
paid
 
as royalty
 
in
 
accordance
 
with
 
the
Petroleum
 
Act
 
of 29
 
November
 
1996
 
No
 
72.
 
The
 
annual
 
general
 
meeting
 
of the
 
company
 
may
by
 
simple
 
majority decide
 
on further instructions
 
concerning
 
the
 
marketing and
 
sale.
exhibit1p2i0
Security Classification: Open
-
Status: Final
Page 3 of 3
Article
 
11
The duties
 
of the nomination
 
committee
 
are to submit
 
a recommendation
 
to
1.
 
the annual general meeting
 
for the election of shareholder-elected members and deputy
members
 
of
 
the
 
corporate
 
assembly
 
and
 
remuneration
 
of members
 
of the
 
corporate
assembly;
2.
 
the
 
annual general meeting for
 
the election and remuneration
 
of members of
 
the
nomination committee;
3.
 
the corporate assembly for
 
the
 
election of shareholder-elected members of the board
of directors
 
and
 
remuneration
 
of the
 
members
 
of
 
the
 
board
 
of
 
directors;
 
and
4.
 
the
 
corporate assembly
 
for
 
the
 
election of the chair and the
 
deputy chair of the
corporate assembly.
The chair
 
of the
 
board
 
of
 
directors
 
and the
 
president
 
and
 
chief executive
 
officer
 
shall be invited,
without
 
having
 
the
 
right
 
to
 
vote,
 
to
 
attend
 
at
 
least
 
one
 
meeting
 
of
 
the
 
nomination
 
committee
before it
 
makes its final
 
recommendation.
The nomination
 
committee
 
consists
 
of four
 
members
 
who must
 
be shareholders
 
or
representatives
 
of shareholders
 
and who
 
shall be independent
 
of the
 
board of
 
directors
 
and the
company's
 
management.
 
The members
 
of the
 
nomination
 
committee,
 
including
 
the chair,
 
shall
be elected
 
by the
 
annual general
 
meeting. The chair
 
of the nomination
 
committee
 
and one other
member
 
shall be
 
elected from
 
among the
 
shareholder
 
-elected members
 
of the corporate
assembly.
 
The members
 
of the
 
nomination
 
committee
 
are normally
 
elected
 
for a
 
term of two
years.
 
Personal
 
deputy
 
members
 
for one
 
or more
 
of the
 
nomination
 
committee's
 
members
 
may
be elected
 
in accordance
 
with the
 
same criteria
 
as described
 
above.
 
A deputy
 
member
 
only
meets for
 
the member
 
if the
 
appointment
 
of that
 
member
 
terminates
 
before the
 
term of
 
office
has expired.
If
 
the
 
appointment
 
of
 
a
 
member
 
of
 
the
 
nomination
 
committee
 
terminates
 
before
 
the
 
term
 
of
office has
 
expired,
 
the
 
election
 
of a
 
new
 
member
 
can
 
be deferred until
 
the next general
 
meeting of
shareholders.
 
If
 
that member
 
has a
 
personal
 
deputy
 
member,
 
the deputy
 
member
 
will function
 
as
a member
 
of
 
the
 
nomination
 
committee
 
until a
 
new
 
election
 
has been
 
held. If
 
the
 
appointment
 
of
the chair
 
terminates
 
before
 
his/her
 
term
 
of office
 
has expired,
 
the committee
 
elects
 
from
 
among
its members
 
a
 
new
 
chair
 
to
 
hold
 
office
 
until the next
 
general
 
meeting
 
of
 
shareholders.
The annual
 
general
 
meeting
 
stipulates the
 
remuneration
 
to
 
be paid to
 
members
 
of the
 
nomination
committee.
 
The company
 
will cover
 
the
 
costs
 
of
 
the
 
nomination
 
committee.
The
 
general
 
meeting
 
may
 
adopt
 
instructions
 
for
 
the
 
nomination
 
committee.
 
 
 
 
EXHIBIT 2.1
 
DESCRIPTION OF SECURITIES
REGISTERED UNDER SECTION 12 OF THE EXCHANGE ACT
As of 31 December 2022, Equinor ASA (“Equinor,” the “company,”
 
“we,” “us,” and “our”) had
the following series of securities registered pursuant to Section 12(b) of the Act:
Title of each class
 
Trading symbol(s)
 
Name of each exchange on
which registered
American Depositary Shares
 
EQNR
 
New York
 
Stock Exchange
Ordinary shares, nominal value of
NOK 2.50 each
 
 
 
New York
 
Stock Exchange*
*
 
Listed, not for trading, but only in connection with the registration of American Depositary
Shares, pursuant to the requirements of the Securities and Exchange Commission (the “SEC”)
Capitalized terms used but not defined herein have the meanings given to them in our annual
report on Form 20-F for the fiscal year ended 31 December 2022 (the “Annual Report”).
ORDINARY SHARES
General
 
This is a summary of material information relating to our share capital, including summaries of
certain provisions of our articles of association and the applicable Norwegian law in effect at
the date of the Annual Report, including the Norwegian Public Limited Companies Act. You
should refer to the full text of our articles of association in English, which is filed as Exhibit 1 to
the Annual Report.
Share Capital
As of 31 December 2022, our authorised share capital was NOK 7,938,675,397.50, divided
into 3,175,470,159 ordinary shares, with a nominal value of NOK 2.50 per ordinary share. The
ordinary shares are in registered form. As of 31 December 2022, 3,121,942,270 ordinary
shares were issued and outstanding (excluding repurchased shares).
We have only one class of shares and all shares have voting rights. The holders of shares are
entitled to receive dividends as and when declared and are entitled to one vote per share at
the annual general meeting of the company.
Authorisation to Acquire Our Own Shares
The annual general meeting authorised on 11 May 2022, the board of directors to acquire
Equinor ASA shares in the market, on behalf of the company, with a nominal value of up to
NOK 187,500,000. The board of directors is authorised to decide at what price within minimum
and maximum prices per share of NOK 50 and NOK 1,000, respectively, and at what time such
acquisition shall take place. Shares acquired pursuant to this authorisation can only be used
for annulment through a reduction of the company’s share capital, pursuant to the Norwegian
Public Limited Liability Companies Act section 12-1. The authorization is valid until the next
annual general meeting, but not beyond 30 June 2023.
Further, on 11
 
May 2022, the annual general meeting authorised the board of directors to
acquire Equinor ASA shares in the market, on behalf of the company, with a nominal value of
up to NOK 38,000,000 to continue operation of the share savings plan for employees. The
board of directors is authorised to decide the price within minimum and maximum prices per
share of NOK 50 and NOK 1,000, respectively, and the time of such acquisition. Shares
acquired pursuant to this authorisation may only be used for sale and transfer to employees of
the Equinor group as a part of the group’s share savings plan and long-term incentive plan, as
approved by the board of directors. The authorization is valid until 30 June 2023.
General Meetings
In accordance with Norwegian law, our annual general meeting of shareholders is required to
be held each year on or prior to June 30. The meeting addresses and decides adoption of the
annual report and accounts, including the distribution of any dividend and any other matters
required by law or the articles of association.
Norwegian law requires that written notice of general meetings be sent to all shareholders
whose addresses are known at least 21 days prior to the date of the meeting. A shareholder
may vote at the general meeting either in person or by proxy.
 
Norwegian law does not require us to send proxy forms to our shareholders for general
meetings as long as such proxy forms are made available on our webpage and the notice for
general meetings includes the link to such website. However, we plan to continue to send
proxy forms with future notices of general meetings.
Our articles of association provide that shareholders may vote in writing, including through
electronic communication, during a specified period before the general meeting. Our board of
directors adopted guidelines for such advance voting in March 2012, and these guidelines are
described in the notices of the annual general meetings.
In addition to the annual general meeting, extraordinary general meetings of shareholders may
be held if deemed necessary by the board of directors, the corporate assembly or the Chair of
the corporate assembly. An extraordinary general meeting must also be convened for the
consideration of specific matters at the written request of our auditors or of shareholders
representing a total of at least 5% of the outstanding share capital.
 
Voting Rights
All of our ordinary shares carry equal right to vote at general meetings. Except as otherwise
provided, decisions which shareholders are entitled to make pursuant to Norwegian law or our
articles of association may be made by a simple majority of the votes cast. In the case of
elections, the persons who obtain the most votes cast are deemed elected. However, certain
decisions, including, but not limited to resolutions to waive preferential rights in connection with
any share issue, to approve a merger or demerger, to amend our articles of association, to
authorise an increase or reduction in our share capital, to issue convertible loans and certain
other financial instruments or to authorise the board of directors to purchase shares, must
receive the approval of at least two-thirds of the aggregate number of votes cast as well as
two-thirds of the share capital represented at a shareholders’ meeting.
 
In general, in order to be entitled to vote, a shareholder must be registered as the owner of
shares in the share register kept by the Norway’s central securities depository,
 
referred to as
the VPS System (described below), or, alternatively,
 
report and show evidence of its share
acquisition to us prior to the general meeting. With effect from 1 July 2023, the Norwegian
Public Limited Liability Companies Act will be amended so that only shareholders who are
registered in the VPS five business days prior to the general meeting will be able to attend and
vote at the general meeting.
 
Beneficial owners of shares which are registered in the name of a nominee are generally not
entitled to vote under Norwegian law, nor are any persons who are designated in the register
as holding such shares as nominees. The beneficial owners of American Depositary Shares
(“ADS”) are therefore only able to vote at meetings by surrendering their ADSs, withdrawing
their ordinary shares from the ADR depositary and registering their ownership of such ordinary
shares directly in our share register in the VPS System. Alternatively, the ADS holder may
instruct the ADR depositary to vote the ordinary shares underlying the ADSs on behalf of the
holder, provided that the ADS holder instructs the ADR depositary to execute a temporary
transfer of the underlying ordinary shares in the VPS System to the beneficial owner. Similarly,
beneficial owners of ordinary shares registered through other VPS-registered nominees may
not be able to vote their shares unless their ownership is reregistered in the name of the
beneficial owner prior to the relevant shareholders’ meeting.
 
With effect from 1 July 2023, the
Norwegian Public Limited Liability Companies Act will be amended so that beneficial owners of
ADSs will no longer need to surrender their ADSs, withdraw their ordinary shares from the
ADR depositary and register their ownership of such ordinary shares directly in our share
register in the VPS System, or arrange for a temporary transfer of the underlying ordinary
share to the beneficial owner, in order to be able to vote at our general meetings. However,
owners of ADSs who wish to attend and vote at our general meetings will, following 1 July
2023, need to give us notice of attendance at least two business days prior the general
meeting. The board of directors may, before notice of general meeting has been sent, decide
on a later deadline.
The Central Securities Depository and Transfer of Shares
Euronext Securities Oslo (Verdipapirsentralen ASA, “ES-OSL” or “VPS”) is Norway’s central
securities depository. It is a computerized bookkeeping system in which the ownership of, and
all transactions relating to, Norwegian listed shares must be recorded. Our share register is
operated through the VPS System.
 
All transactions relating to securities registered with the VPS System are made through
computerized book entries. No physical share certificates are or can be issued. The VPS
System confirms each entry by sending a transcript to the registered shareholder regardless of
beneficial ownership. To
 
effect these entries, the individual shareholder must establish a
securities’ account with a Norwegian account agent. Norwegian banks, the Central Bank of
Norway, authorised investment firms in Norway,
 
and Norwegian branches of credit institutions
established within the European Economic Area are allowed to act as account agents.
The entry of a transaction in the VPS System is
prima facie
 
evidence in determining the legal
rights of parties as against the issuing company or a third party claiming an interest in the
subject security.
 
The VPS System is liable for any loss suffered as a result of faulty registration or an
amendment to, or deletion of, rights in respect of registered securities unless the error is
caused by matters outside the VPS’ control, the consequences of which the VPS could not
reasonably be expected to avoid or overcome. Damages payable by the VPS may, however,
be reduced in the event of contributory negligence by the aggrieved party. A transferee or
assignee of shares may not exercise the rights of a shareholder with respect to his or her
shares unless that transferee or assignee has registered his or her shareholding or has
reported and shown evidence of such share acquisition and the acquisition of such shares is
not prevented by law, our articles of association or otherwise.
Amendments to our Articles of Association, including Variation of Rights
The affirmative vote of at least two-thirds of the votes cast and of the share capital represented
at the general meeting is required to amend our articles of association. Any amendment, or
other resolution, which would reduce any shareholder’s right in respect of dividend payments
or other rights to our assets or restrict the transferability of shares requires a majority vote of at
least 90% of the aggregate share capital represented in a general meeting, as well as the
majority required for the amendment of the articles of association. Because the Norwegian
State, acting through the Ministry of Trade, Industry and Fisheries, holds more than two-thirds
of the shares in the company, it currently practically has the sole power to amend our articles
of association.
Certain types of changes in the rights of our shareholders require the consent of all affected
shareholders. If such resolutions only affect some of the shareholders, the resolutions require
the support of all affected shareholders, as well as the majority required for the amendment of
the articles of association.
Additional Issuances and Preferential Rights
If we issue any new shares, including bonus share issues, our articles of association must be
amended, which requires the same vote as other amendments to our articles of association. In
addition, under Norwegian law, our shareholders have a preferential right to subscribe to new
shares issued by us. The preferential rights to subscribe to an issue may be waived by a
resolution in a general meeting passed by the same percentage threshold required to approve
amendments to our articles of association.
The general meeting may,
 
with a majority vote as described above, authorise the board of
directors to issue new shares, and to waive the preferential rights of shareholders in
connection with such issuances. Such authorisation may be effective for a maximum of two
years, and the total par value of the shares to be issued may not exceed 50% of the registered
share capital when the authorisation is registered in the Norwegian Register of Business
Enterprises.
The issuance of shares to holders who are citizens or residents of the United States upon the
exercise of preferential rights may require us to file a registration statement in the United
States under United States securities laws. If we decide not to file a registration statement,
these holders may not be able to exercise their preferential rights.
 
Under Norwegian law, bonus share issues may be distributed, subject to shareholder approval,
by transfer from our distributable equity. Any bonus issues may be effected
 
either by issuing
shares or by increasing the par value of the shares outstanding.
Minority Rights
Norwegian law contains a number of protections for minority shareholders against oppression
by the majority including but not limited to those described in this paragraph Any shareholder
may petition the courts to have a decision of the general meeting declared invalid on the
grounds that it was unlawfully adopted or is otherwise in conflict with statute or the articles of
association of the company. In certain grave circumstances shareholders may require the
courts to dissolve the company as a result of such a decision. A shareholder may also demand
a dissolution if any of the company’s bodies has adopted a decision which is suited to give
certain shareholders or others an unreasonable benefit at the expense of other shareholders or
the company.
 
Minority shareholders holding 5% or more of our share capital have a right to demand that we
hold an extraordinary general meeting to discuss or resolve specific matters. In addition, any
shareholder may demand that we place an item on the agenda for any general meeting if we
are notified at least within seven days before the deadline for convening the general meeting.
 
Mandatory Bid Requirement
Norwegian law requires any person, entity or consolidated group that acquires more than one-
third of the voting rights of a Norwegian company listed on a Norwegian regulated market,
such as the Oslo Stock Exchange (“OSE”), to make, within four weeks of such acquisition, an
unconditional general offer to acquire the remaining shares in that company.
 
The mandatory
bid obligation ceases to apply if the person subject to the obligation disposes of the portion of
shares exceeding the mandatory bid threshold within such four week period. The party must
immediately notify the stock exchange and the company when it enters into an agreement to
acquire shares that will trigger the duty to make a mandatory offer. Until a bid is made, or a
sale is effective, the relevant party cannot vote the portion of its shares which exceeds the
mandatory bid threshold or exercise any rights of share ownership in respect of such shares,
other than the right to receive dividends and preferential rights in the event of a share capital
increase.
The offer is subject to approval by the Oslo Stock Exchange in its capacity as Norwegian
takeover supervisory authority before submission of the offer to the shareholders. The offer
must be in cash or contain a cash alternative at least equivalent to any other consideration
offered. The bid price shall be at least as high as the highest payment the offeror has made or
agreed to make in the six-month prior to the time the mandatory bid obligation was triggered,
but equal to the market price if it is clear that the market price was higher at the point the
mandatory bid obligation was triggered. The period for acceptance of the bid must be within
four and six weeks.
A shareholder that fails to make a bid within the four week period may not, as long as the
mandatory bid requirement applies and unless the remaining shareholders so approve,
exercise rights of share ownership with respect to all its shares other than the right to receive
dividends and preferential rights in the event of a share capital increase. In addition, the
takeover supervisory authority may impose a daily fine upon a shareholder who fails to make
the required offer. If no bid is made, and the period allowed for sale is exceeded, the takeover
supervisory authority may sell the shares under the rules governing forced sales.
Any person, entity or consolidated group that owns shares representing more than one-third of
the voting rights in a company is obliged to make an offer to acquire the remaining shares of
the company if the person, entity or consolidated group becomes the owner of shares
representing 40% or more of the voting rights in the company through an acquisition (repeated
mandatory offer obligation). The same applies if the shareholder becomes the owner of 50% or
more of the voting rights in the company through an acquisition.
Compulsory Acquisition
A shareholder who, directly or via subsidiaries, acquires shares representing more than 90% of
the total number of issued shares, as well as more than 90% of the total voting rights, has the
right to effect a compulsory acquisition for cash of any shares not already owned by the
majority shareholder (and each remaining minority shareholder of that company would have
the right to require the majority shareholder to effect a compulsory acquisition for cash of the
shares not already owned by such majority shareholder). A compulsory acquisition has the
effect that the majority shareholder becomes the owner of the shares of the minority
shareholders with immediate effect.
A majority shareholder who effects a compulsory acquisition is required to offer the minority
shareholders a specific price per share. The determination of the offer price is at the discretion
of the majority shareholder. However,
 
where the shareholder, after making a mandatory or
voluntary offer, has acquired more than 90% of the voting shares of a company and a
corresponding proportion of the voting rights, and the shareholder completes a compulsory
acquisition of the remaining shares within three months after the expiry of the offer period, the
redemption price shall be determined on the basis of the offer price in the mandatory /
voluntary offer unless specific reasons indicate another price.
Should any minority shareholder not accept the offered price, such minority shareholder must
notify the majority shareholder within a specified period of not less than two months. If the
parties do not come to an agreement on the offer price, each party can request that the price
be set by the Norwegian courts. The cost of such court procedure would normally be charged
to the account of the majority shareholder, and the courts would have full discretion in
determining the consideration due to the minority shareholder as a result of the compulsory
acquisition on the basis of the true value of the company.
Our Directors and Corporate Assembly
We have a corporate assembly comprising 18 members. At the general meeting of
shareholders, two-thirds of the members of the corporate assembly are normally elected for a
term of two years, together with deputy members, while the remaining one-third, together with
deputy members, are elected by and from among our employees. There is no quorum
requirement, and nominees who receive the most votes are elected. Any shareholder at the
meeting may place nominations before the meeting. A member of the corporate assembly
(other than a member elected by employees) may be removed by the shareholders at any time
without cause.
We have a nomination committee that makes recommendations to the general meeting
regarding the election of shareholder-elected members of the corporate assembly and their
deputies. The committee consists of four members who must be shareholders or
representatives of shareholders and who must be independent of the board of directors and
the company’s management. The members of the nomination committee, including the chair,
are elected by the annual general meeting. The chair of the committee and one other member
are elected among the shareholder-elected members of the corporate assembly. Each
member is elected for a two-year term.
 
Our articles of association provide that the board of directors consists of 9 to 11 directors. Our
directors are elected by our corporate assembly to the board of directors for a period of up to
two years and may also be removed from office by our corporate assembly. If
 
requested by at
least one third of the members of the corporate assembly, up to one-third of the directors must
be employee representatives. Our nomination committee makes recommendations to the
corporate assembly regarding the election of shareholder-elected directors of the board and
their deputies (if any). Half of the corporate assembly members elected by the employees may
demand that the members of the board of directors be elected by the shareholder-elected
members of the corporate assembly and the employee-elected members of the corporate
assembly, each
 
voting as a separate group. A director (other than a director elected directly by
the employee members) may be removed at any time by the corporate assembly without
cause.
The corporate assembly makes decisions by majority vote, and more than half must be present
for a quorum. If votes are tied, the chair of the meeting casts the deciding vote.
Payment of Dividends
We announce dividends on a quarterly basis. The board of directors approves first to third
quarter interim dividends based on an authorisation from the general meeting, while the annual
general meeting approves the fourth quarter (and total annual) dividend based on a proposal
from the board. When deciding the interim dividends and recommending the total annual
dividend level, the board of directors will take into consideration expected cash flow, capital
expenditure plans, financing requirements and appropriate financial flexibility.
 
In addition to cash dividends, Equinor might buy back shares as part of the distribution of
capital to the shareholders.
The shareholders at the annual general meeting may vote to reduce, but may not increase, the
dividend proposed by the board of directors. Equinor announces dividend payments in
connection with quarterly results. Payment of quarterly dividends is expected to take place
approximately four months after the announcement of each quarterly dividend.
Equinor declares dividends in USD. Dividends in NOK per share will be calculated and
communicated four business days after record date for shareholders at Oslo Børs.
Rights of Redemption and Repurchase of Shares
Our articles of association do not authorise the redemption of shares. In the absence of
authorisation, the redemption of shares may still be decided by a general meeting of
shareholders by a two-thirds majority under certain conditions. However, the share redemption
would, for all practical purposes, depend on the consent of all shareholders whose shares are
redeemed.
A Norwegian company may purchase its own shares if an authorisation to do so has been
given by a general meeting with the approval of at least two-thirds of the aggregate number of
votes cast as well as twothirds of the share capital represented at the meeting. The aggregate
par value of treasury shares held by the company must not exceed 10% of the company’s
share capital and treasury shares may only be acquired if the company’s distributable equity,
according to the latest adopted balance sheet, exceeds the consideration to be paid for the
shares. The authorisation by the general meeting cannot be given for a period exceeding two
years. See “Authorisation to Acquire Our Own Shares” above.
Shareholders’ Votes on Certain Reorganizations
A decision to merge with another company or to demerge requires a resolution of our
shareholders at a general meeting passed by a two-thirds majority of the aggregate votes cast
as well as two-thirds of the aggregate share capital represented at the general meeting. A
merger plan or demerger plan signed by the board of directors along with certain other
required documentation must be made available to the shareholders on the company’s website
at least one month prior to the shareholders’ meeting.
 
Material Agreements
 
The general meeting must approve any material agreement between Equinor and a related
party. A material agreement comprises agreements under which the fair value of the
company’s obligations exceed 2.5% of Equinor’s total equity and liabilities, as presented on its
last approved annual financial statement. In voting on whether to grant such approval, voting
rights cannot be exercised in respect of shares held by the related party or by another
enterprise in the same company group. The general meeting’s approval is not required for
agreements concluded with a wholly owned subsidiary or in the ordinary course of business
entered into on customary business terms and principles. Additional exceptions follow from the
Norwegian Public Limited Companies Act.
 
Liability of Directors
Our directors, the Chief Executive Officer and the members of the corporate assembly owe a
fiduciary duty to the company and its shareholders. Their fiduciary duty requires that they act in
our best interests when exercising their functions and exercise a general duty of loyalty and
care toward us. Their principal task is to safeguard the interests of the company.
Our directors, the Chief Executive Officer and the members of the corporate assembly can
each be held liable for any damage they negligently or willfully cause us. Norwegian law
permits the general meeting to exempt any such person from liability, but the exemption is not
binding if substantially correct and complete information was not provided at the general
meeting when the decision was taken. If a resolution to grant such exemption from liability or to
not pursue claims against such a person has been passed by a general meeting with a smaller
majority than that required to amend our articles of association, shareholders representing
more than 10% of the share capital or (if there are more than 100 shareholders) more than
10% of the number of shareholders may pursue the claim on our behalf and in our name. The
cost of any such action is not our responsibility, but can be recovered by any proceeds we
receive as a result of the action. If the decision to grant exemption from liability or to not pursue
claims is made by such a majority as is necessary to amend the articles of association, the
minority shareholders cannot pursue the claim in our name.
Indemnification of Directors and Officers
Neither Norwegian law nor our articles of association contain any provision concerning
indemnification by us of our board of directors.
 
Distribution of Assets on Liquidation
Under Norwegian law, a company may be wound-up by a resolution of the company’s
shareholders in a general meeting passed by both a two-thirds majority of the aggregate votes
cast and two-thirds of the aggregate share capital represented at the meeting. The shares rank
equal in the event of a return on capital by the company upon a winding-up or otherwise.
Exchange Controls and Other Limitations Affecting Shareholders of a Norwegian
Company
Under the Norwegian foreign exchange control law, transfers of capital to and from Norway are
not subject to prior government approval. An exception applies to the physical transfer of
payments in currency exceeding certain thresholds, which must be declared to the Norwegian
custom authorities. This means that non-Norwegian resident shareholders may receive
dividend payments without Norwegian exchange control consent as long as the payment is
made through an institution licensed to provide payment services. Transferring banks are
required to submit reports on foreign currency exchange transactions into and out of Norway
into a central data register maintained by the Norwegian tax authorities. The Norwegian police,
tax authorities, customs and excise authorities, the Labour and Welfare Administration and the
Norwegian FSA have electronic access to the data in this register, and certain other entities
also have access such as the Norwegian central bank, the Norwegian Ministry of Foreign
Affairs and trustees in bankruptcy estates.
There are no restrictions affecting the rights of non-Norwegian residents or foreign owners to
hold or vote for our shares.
AMERICAN DEPOSITARY
 
SHARES
This section summarizes certain material provisions of the Amended and Restated Deposit
Agreement, dated as of 4 February 2019, among Equinor ASA, JPMorgan Chase Bank, N.A.,
as depositary, and the holders from time to time of American Depositary Receipts (“ADRs”).
We refer to this agreement as the “deposit agreement.” We do not, however,
 
describe every
aspect of the deposit agreement, which has been filed as an exhibit to our registration
statement on Form F-6, filed on 13 October 2022. You
 
should read the deposit agreement for a
more detailed description of the terms of the ADRs. Additional copies of the deposit agreement
are available for inspection at the principal office of the depositary in New York,
 
which is
presently located at 383 Madison Avenue, Floor 11,
 
New York,
 
New York, 10179.
American Depositary Receipts
The depositary issued ADRs evidencing American depositary shares pursuant to the deposit
agreement. Each ADS represents one ordinary share. Only persons in whose names ADRs
are registered on the books of the depositary will be treated by the depositary and us as
holders of ADRs. Unless certificated ADRs are specifically requested by you, all ADSs will be
issued on the books of our depositary in book-entry form and periodic statements will be
mailed to you which reflect your ownership interest in such ADSs. In our description,
references to American depositary receipts or ADRs shall include the statements you will
receive which reflect your ownership of ADSs.
You
 
may hold ADSs either directly or indirectly through your broker or other financial institution.
If you hold ADSs directly, by having an ADS registered in your name on the books of the
depositary, you are an ADR holder.
 
This description assumes you hold your ADSs directly. If
you hold the ADSs through your broker or financial institution nominee, you must rely on the
procedures of such broker or financial institution to assert the rights of an ADR holder
described herein. You
 
should consult with your broker or financial institution to find out what
those procedures are.
Pursuant to the terms of the deposit agreement, registered holders of ADRs and all persons
holding any interest in ADRs and/or ADSs will be subject to any applicable disclosure
requirements regarding acquisition and ownership of, or interests in, ordinary shares as are
applicable pursuant to the terms of our articles of association or other provisions of or
governing the ordinary shares. In order to enforce such disclosure requirements, we reserve
the right to instruct ADR holders to deliver their ADSs for cancellation and withdrawal of the
deposited securities so as to permit us to deal directly with the holder thereof as a holder of
ordinary shares, and, by being a holder of an ADR, ADR holders are contractually agreeing to
comply with such instructions. The depositary has agreed, subject to the terms and conditions
of the deposit agreement, to cooperate with Equinor in its efforts to inform ADR holders of any
exercise by us of our rights to instruct ADR holders to deliver their ADSs for cancellation, and
to consult with and provide us with reasonable assistance without risk, liability or expense on
the part of the depositary, on the manner or manners in which we may enforce such rights with
respect to any ADR holder.
The depositary will keep, at its transfer office, (i) a register for the registration, registration of
transfer, combination and split-up of ADRs, which at all reasonable times will be open for
inspection by holders of ADRs and us for the purpose of communicating with holders in the
interest of our business or a matter relating to the deposit agreement and (ii) facilities for the
delivery and receipt of ADRs.
Deposit, Transfer and Withdrawal
The depositary has agreed that upon delivery of our ordinary shares (or rights to receive our
ordinary shares from us or any registrar, transfer agent, clearing agency or other entity
recording ordinary share ownership or transactions for us) to their custodian, which is currently
Nordea Bank Norge ASA, and in accordance with the procedures set forth in the deposit
agreement, the depositary will issue ADRs for delivery at its designated transfer office.
Upon surrender at the office of the depositary of an ADR for the purpose of withdrawal of the
deposited securities represented by the ADSs evidenced by such ADR, and upon payment of
the fees, governmental charges and taxes provided in the deposit agreement, and subject to
the terms and conditions of the deposit agreement, the holder of such ADR will be entitled to
delivery to such holder or upon such holder’s order, as permitted by applicable law,
 
of the
amount of deposited securities at the time represented by the ADS evidenced by such ADR.
The custodian will ordinarily deliver such deposited securities at or from its office. The
forwarding of deposited securities for delivery at any other place specified by the holder will be
at the risk and expense of the holder.
Dividends, Other Distributions and Rights
To
 
the extent practicable, the depositary will distribute to you, in proportion to the number of
ADSs you hold, any U.S. dollars available to the depositary resulting from a cash dividend or
other cash distribution or the net proceeds of sales of any other distribution that it receives in
respect of the deposited securities. Such a distribution will be subject to (i) appropriate
adjustments for taxes withheld, (ii) the impermissibility or impracticability of such distribution
with respect to certain holders and (iii) the deduction of the depositary and/or its agents’ fees
and expenses in (1) converting any foreign currency to U.S. dollars by sale or in such other
manner as the depositary may determine, to the extent that it determines that such conversion
may be made on a reasonable basis, (2) transferring foreign currency or U.S. dollars to the
United States by such means as the depositary may determine, to the extent that it determines
that such transfer may be made on a reasonable basis, (3) obtaining any approval or license of
any governmental authority required for such conversion or transfer, which is obtainable at a
reasonable cost and within a reasonable time and (4) making any sale by public or private
means in any commercially reasonable manner. To
 
the extent that the depositary determines
in its discretion that any distribution under the terms of the deposit agreement is not practicable
with respect to any holder, the depositary may make such distribution as it so deems
practicable, including the distribution of foreign currency, securities or property (or appropriate
documents evidencing the right to receive foreign currency, securities or property) or the
retention thereof as deposited securities with respect to such holder’s ADRs (without liability for
interest thereon or the investment thereof). See “Ordinary Shares—Payment of Dividends”
above.
If any distribution on deposited securities consists of a dividend in, or free distribution of,
ordinary shares, the depositary will, to the extent practicable, distribute to you, in proportion to
the number of ADSs you hold, additional ADRs evidencing an aggregate number of ADSs that
represents the amount of ordinary shares received as such dividend or free distribution. In lieu
of delivering ADRs for fractional ADSs in the event of any such dividend or free distribution, the
depositary shall sell the number of ordinary shares represented by the aggregate of such
fractions and distribute the net proceeds to holders entitled thereto.
If we offer or cause to be offered to holders of deposited securities any rights to subscribe for
additional shares or rights of any nature, the depositary will to the extent practicable distribute
warrants or other instruments, in its discretion, representing rights to acquire additional ADRs
in respect of any rights that have been made available to the depositary as a result of a
distribution on deposited securities, to the extent that we timely furnish to the depositary
evidence satisfactory to the depositary that the depositary may lawfully distribute the same. We
have no obligation to furnish such evidence, and to the extent that we do not furnish such
evidence and the sales of rights are practicable, the depositary will distribute any U.S. dollars
available to the depositary from the net proceeds of sales of rights, as in the case of cash, or,
to the extent that we do not furnish such evidence and such sales cannot practicably be
accomplished by reason of the non-transferability of the rights, limited markets therefor, their
short duration, or otherwise, the depositary will distribute nothing (and any rights may lapse).
The depositary will not offer rights to holders having an address in the U.S. unless both the
rights and the securities to which such rights relate are either exempt from registration under
the Securities Act of 1933, as amended (the “Securities Act”) with respect to a distribution to all
holders or are registered under the provisions of the Securities Act. Notwithstanding any terms
of the deposit agreement to the contrary, we shall have no obligation to prepare and file a
registration statement in respect of any such rights.
Whenever the depositary shall receive any distribution other than cash, ordinary shares or
rights in respect of the deposited securities, the depositary will to the extent practicable
distribute securities or property available to the depositary resulting from such distribution to
the holders entitled thereto by any means that the depositary may deem equitable and
practicable, or, to the extent that the depositary deems distribution of such securities or
property to not be equitable and practicable, any U.S. dollars available to the depositary from
the net proceeds of sales of such securities or property, as in the case of cash.
Whenever we intend to distribute a dividend payable at the election of the holders of ordinary
shares in cash or in additional shares, we shall give notice thereof to the depositary at least 30
days prior to the proposed distribution stating whether or not we wish such elective distribution
to be made available to ADR holders. Upon receipt of notice indicating that we wish such
elective distribution to be made available to ADR holders, the depositary shall consult with us
to determine, and we shall assist the depositary in its determination, whether it is lawful and
reasonably practicable to make such elective distribution available to the ADR holders. The
depositary shall make such elective distribution available to ADR holders only if (i) we shall
have timely requested that the elective distribution is available to ADR holders, (ii) the
depositary shall have determined that such distribution is reasonably practicable and (iii) the
depositary shall have received satisfactory documentation within the terms of the deposit
agreement including, without limitation, any legal opinions of counsel in any applicable
jurisdiction that the depositary in its reasonable discretion may request, at our expense. If the
above conditions are not satisfied, the depositary shall, to the extent permitted by law,
distribute to the ADR holders, on the basis of the same determination as is made in the local
market in respect of the ordinary shares for which no election is made, either (x) cash or (y)
additional ADSs representing such additional ordinary shares. If the above conditions are
satisfied, the depositary shall establish a record date and establish procedures to enable ADR
holders to elect the receipt of the proposed dividend in cash or in additional ADSs. We shall
assist the depositary in establishing such procedures to the extent necessary. Nothing herein
shall obligate the depositary to make available to ADR holders a method to receive the elective
dividend in ordinary shares (rather than ADSs). There can be no assurance that ADR holders
generally, or any holder in particular,
 
will be given the opportunity to receive elective
distributions on the same terms and conditions as the holders of ordinary shares.
If the depositary determines that any distribution of property other than cash (including ordinary
shares or rights) on deposited securities is subject to any tax which the depositary or the
custodian is obligated to withhold, the depositary may dispose of all or a portion of such
property in such amounts and in such manner as the depositary deems necessary and
practicable to pay such taxes, by public or private sale, and the depositary will distribute the
net proceeds of any such sale or the balance of any such property after deduction of such
taxes to the holders entitled thereto.
Changes Affecting Deposited Securities
Pursuant to the terms of the deposit agreement, the depositary may, in its discretion, and will if
we so reasonably request, amend the ADRs or distribute additional or amended ADRs (with or
without calling for the exchange of any ADRs) or cash, securities or property on the record
date set by the depositary therefor to reflect any change in par value, split-up, consolidation,
cancellation or other reclassification of deposited securities, any share distribution or any
distribution other than cash, ordinary shares or rights, which in each case is not distributed to
holders or any cash, securities or property available to the depositary in respect of the
deposited securities from (and the depositary is authorised to surrender any deposited
securities to any person and, irrespective of whether such deposited securities are surrendered
or otherwise cancelled by operation of law, rule, regulation or otherwise, to sell by public or
private sale any property received in connection with) any recapitalization, reorganization,
merger, consolidation, liquidation, receivership, bankruptcy or sale of all or substantially all of
our assets, and to the extent that the depositary does not so amend the ADRs or make a
distribution to holders to reflect any of the foregoing, or the net proceeds thereof, whatever
cash, securities or property results from any of the foregoing shall constitute deposited
securities and each ADS evidenced by an ADR shall automatically represent its pro rata
interest in the deposited securities as then constituted. Promptly upon the occurrence of any of
the aforementioned changes affecting deposited securities, we shall notify the depositary in
writing of such occurrence and as soon as practicable after receipt of such notice, may instruct
the depositary to give notice thereof, at our expense, to holders in accordance with the
provisions of the deposit agreement. Upon receipt of such instruction, the depositary shall give
notice to the holders in accordance with the terms of the deposit agreement, as soon as
reasonably practicable.
Record Dates
The depositary may, after consultation with us if practicable, fix a record date (which, to the
extent applicable, shall be as near as practicable to any corresponding record date set by us)
for the determination of the holders who shall be responsible for the fee assessed by the
depositary for administration of the ADR program and for any expenses provided in the deposit
agreement as well as for the determination of the holders who shall be entitled to receive any
distribution on or in respect of deposited securities, to give instructions for the exercise of any
voting rights, to receive any notice or to act in respect of other matters and only such holders
shall be so entitled or obligated.
Voting of Deposited Securities
Subject to the following sentence, as soon as practicable after receipt of notice of any
meetings at which the holders of ordinary shares are entitled to vote, or of solicitation of
consents or proxies from holders of ordinary shares or other deposited securities, the
depositary shall fix the ADS record date in accordance with the deposit agreement in respect
of such meeting or solicitation of consent or proxy. The depositary shall, if we request in writing
in a timely manner (the depositary having no obligation to take any further action if the request
shall not have been received by the depositary at least 30 days prior to the date of such vote or
meeting) and at our expense and provided no legal prohibitions exist, distribute to holders a
notice stating:
1. such information as is contained in such notice and any solicitation materials;
2. that each holder on the record date set by the depositary therefor will, subject to any
applicable provisions of Norwegian law, be entitled to instruct the depositary as to the exercise
of the voting rights, if any, pertaining to the deposited securities represented by the ADSs
evidenced by such holder’s ADRs; and
3. the manner in which such instructions may be given, including without limitation, any
requirements that ADSs be blocked for a specified period of time leading up to and including
the date of such meeting or solicitation and/or ordinary shares represented by ADSs for which
instructions are provided be registered on the books of Equinor in the name of the instructing
holder.
Upon actual receipt by the ADR department of the depositary of instructions of a holder on
such record date in the manner and on or before the time established by the depositary for
such purpose and timely compliance by the ADR holder with any requirements notified by the
depositary, the depositary shall endeavor,
 
insofar as practicable and permitted under the
provisions of, or governing, deposited securities, to vote or cause to be voted the deposited
securities represented by such holder’s ADRs in accordance with such instructions. The
depositary will not itself exercise any voting discretion in respect of any deposited securities.
There is no guarantee that holders generally or any holder in particular will receive the notice
described above with sufficient time to comply with the voting requirements set forth in the
notice referenced above or to enable such holder to return any voting instructions to the
depositary in a timely manner.
 
Notwithstanding anything contained in the deposit agreement or any ADR, the depositary may,
to the extent not prohibited by law or regulations, or by the requirements of the stock exchange
on which the ADSs are listed, in lieu of distribution of the materials provided to the depositary
in connection with any meeting of, or solicitation of consents or proxies from, holders of
deposited securities, distribute to holders of ADRs a notice that provides such holders with, or
otherwise publicizes to such holders, instructions on how to retrieve such materials or receive
such materials upon request (i.e., by reference to a website containing the materials for
retrieval or a contact for requesting copies of the materials).
ADR holders are strongly encouraged to forward their voting instructions as soon as possible.
Voting instructions will not be deemed received until such time as the ADR department
responsible for proxies and voting has received such instructions notwithstanding that such
instructions may have been physically received by the depositary prior to such time.
 
The depositary and its agents may rely and shall be protected in acting upon the opinion(s) of
our counsels with respect to all matters relating to voting under Norwegian Law, rule and/or
regulation.
Reports and Other Communications
We have delivered to the depositary,
 
the custodian and any transfer office, on the SEC’s
website, or upon request from the depositary (which request may be refused by the depositary
at its discretion), a copy of all provisions of or governing the ordinary shares and any other
deposited securities issued by us or any of our affiliates and, promptly upon any change
thereto, we will deliver to the depositary, the custodian and any transfer office,
 
a copy (in
English or with an English translation) of such provisions as so changed.
Amendment and Termination of the Deposit Agreement
Subject to the provisions of the deposit agreement, the ADRs and the deposit agreement may
at any time be amended by us and the depositary without your consent; provided that any
amendment that imposes or increases any fees or charges (other than stock transfer or other
taxes and other governmental charges, transfer or registration fees, SWIFT,
 
cable, telex or
facsimile transmission costs, delivery costs or other such expenses), or which otherwise
prejudices any substantial existing right of yours, will take effect 30 days after notice of any
such amendment has been given to ADR holders. Every holder of an ADR at the time any
amendment to the deposit agreement so becomes effective will be deemed by continuing to
hold such ADRs to consent and agree to such amendment and to be bound by the deposit
agreement as amended thereby. In no event may any amendment impair the right of any
holder of ADRs to surrender such ADRs and receive the deposited securities represented
thereby, except
 
in order to comply with mandatory provisions of applicable law.
Any amendments or supplements which (i) are reasonably necessary (as agreed by us and the
depositary) in order for (a) the ADSs to be registered under the Securities Act or (b) the ADSs
or our ordinary shares to be traded solely in electronic book-entry form and (ii) do not in either
such case impose or increase any fees or charges to be borne by holders of ADRs, shall be
deemed not to prejudice any substantial rights of such holders. Notwithstanding the foregoing,
if any governmental body or regulatory body should adopt new laws, rules or regulations which
would require amendment or supplement of the deposit agreement or the form of ADR to
ensure compliance therewith, we and the depositary may amend or supplement the deposit
agreement and the form of ADR at any time in accordance with such changed laws, rules or
regulations. Such amendment or supplement to the deposit agreement in such circumstances
may become effective before a notice of such amendment or supplement is given to holders of
ADRs or within any other period of time as required for compliance. Notice of any amendment
to the deposit agreement or form of ADR shall not need to describe in detail the specific
amendments effectuated thereby,
 
and failure to describe the specific amendments in any such
notice shall not render such notice invalid, provided, however, that, in each such case, the
notice given to the holders identifies a means for holders to retrieve or receive the text of such
amendment (i.e., upon retrieval from the SEC’s, the depositary’s or our website or upon
request from the depositary).
The depositary may, and shall at our written direction, terminate the deposit agreement and the
ADRs by mailing notice of such termination to the ADR holders at least 30 days prior to the
date fixed in such notice for such termination; provided, however, if the depositary shall have
(i) resigned as depositary, notice of such termination by the depositary shall not be provided to
ADR holders unless a successor depositary shall not be operating under the deposit
agreement within 60 days of the date of such resignation, or (ii) been removed as depositary,
notice of such termination by the depositary shall not be provided to ADR holders unless a
successor depositary shall not be operating under the deposit agreement on the 60th day after
our notice of removal was first provided to the depositary. Notwithstanding anything to the
 
 
contrary set forth in the deposit agreement, the depositary may terminate the deposit
agreement without notice to us, but subject to giving 30 days’ notice to the ADR holders, under
the following circumstances: (i) in the event of the our bankruptcy or insolvency, (ii) if the
ordinary shares cease to be listed on an internationally recognized stock exchange, (iii) if we
effect (or will effect) a redemption of all or substantially all of the deposited securities, or a cash
or share distribution representing a return of all or substantially all of the value of the deposited
securities, or (iv) there occurs a merger, consolidation, sale of assets or other transaction as a
result of which securities or other property are delivered in exchange for or in lieu of deposited
securities.
After the date so fixed for termination, the depositary and its agents will perform no further acts
under the deposit agreement and the ADRs, except to receive and hold (or sell) distributions
on deposited securities and deliver deposited securities being withdrawn. As soon as
practicable after the date so fixed for termination, the depositary shall use its reasonable efforts
to sell the deposited securities and shall thereafter (as long as it may lawfully do so) hold in an
account (which may be segregated or unsegregated account) the net proceeds of such sales,
together with any other cash then held by it under the deposit agreement, without liability for
interest, in trust for the pro rata benefit of the holders of ADRs not theretofore surrendered.
After making such sale, the depositary shall be discharged from all obligations in respect of the
deposit agreement and the ADRs, except to account for such net proceeds and other cash.
After the date so fixed for termination, we shall be discharged from all obligations under the
deposit agreement except for our obligations to the depositary and its agents.
In the event that the depositary resigns, is removed or is otherwise substituted, and a
successor thereto is appointed, the successor depositary will promptly mail you notice of such
appointment.
Liability of Holder for Taxes
If any tax or other governmental charges (including any penalties and/or interest) become
payable by the custodian or the depositary with respect to any ADR, any deposited securities
represented by the ADSs evidenced thereby or any distribution thereon, such tax or other
governmental charge will be paid by the holder thereof to the depositary and by holding or
having held an ADR the holder and all prior holders, jointly and severally, agree to indemnify,
defend and hold harmless each of the depositary and its agents in respect thereof. The
depositary may refuse to effect any registration, registration of transfer or any split-up or
combination of such ADR or any withdrawal of deposited securities underlying such ADR until
such payment is made. The depositary may also deduct from any dividends or other
distributions or may sell by public or private sale for your account any part or all of the
deposited securities underlying such ADR and may apply such dividends, distributions or the
proceeds of any such sale to pay any such tax or other governmental charges, and the holder
of such ADR shall remain liable for any deficiency, and the depositary shall reduce the number
of ADSs evidenced thereby to reflect any such sales of shares. In connection with any
distribution to holders, we will remit to the appropriate governmental authority or agency all
amounts (if any) required to be withheld and owing to such authority or agency by us; and the
depositary and the custodian will remit to the appropriate governmental authority or agency all
amounts (if any) required to be withheld and owing to such authority or agency by the
depositary or the custodian. If the depositary determines that any distribution in property other
than cash (including shares or rights) on deposited securities is subject to any tax that the
depositary or the custodian is obligated to withhold, the depositary may dispose of all or a
portion of such property in such amounts and in such manner as the depositary deems
necessary and practicable to pay such taxes, by public or private sale, and the depositary shall
distribute the net proceeds of any such sale or the balance of any such property after
deduction of such taxes to the holders entitled thereto. Each holder of an ADR or an interest
therein agrees to indemnify the depositary, us, the custodian and any of their respective
officers, directors, employees, agents and affiliates against, and hold each of them harmless
from, any claims by any governmental authority with respect to taxes, additions to tax,
penalties or interest arising out of any refund of taxes, reduced rate of withholding at source or
other tax benefit obtained, which obligations shall survive any transfer or surrender of ADSs or
the termination of the deposit agreement.
Transfer of American Depositary Receipts
The ADRs are transferable on the books of the depositary,
provided
 
that the depositary may
close the transfer books or any portion thereof at any time or from time to time when deemed
expedient by it, and may also close the issuance book portion of the transfer books when
reasonably requested by us solely in order to enable us to comply with applicable law. As a
condition precedent to the issue, registration, registration of transfer, split-up or combination of
any ADR, the delivery of any distribution thereon, or withdrawal of any deposited securities, the
depositary, we or the custodian may require (i) payment of a sum sufficient
 
to reimburse it for
any tax or other governmental charge and any stock transfer or registration fee with respect
thereto (including any such tax or charge and fee with respect to ordinary shares being
deposited or withdrawn) and payment of any applicable fees payable by the holders of ADRs
under the deposit agreement, (ii) proof of the identity of any signatory and genuineness of any
signature, (iii) information as to citizenship or residence, exchange control approval, beneficial
ownership of any securities, compliance with applicable law, regulations, provisions of or
governing the deposited securities and terms of the deposit agreement and the ADR or other
information as it may deem necessary or proper, and (iv) compliance with such regulations as
the depositary may establish consistent with the deposit agreement. The issuance, transfer,
combination or split-up of ADRs or the withdrawal of deposited securities may be suspended,
generally or in particular instances, during any period when the transfer books of the
depositary or the books of Equinor or its agent for the registration and transfer of ordinary
shares are closed or if any such action is deemed advisable by the depositary.
Limitations on Liability
Neither the depositary nor we nor any of our respective directors, officers, employees, agents
or affiliates will be liable to you if by reason of any provision of any present or future law, rule,
regulation, fiat, order or decree of the United States, the Kingdom of Norway or any other
country or jurisdiction, or of any other governmental or regulatory authority or securities
exchange or market or automated quotation system, or by reason of any provision of or
governing any deposited securities or any provision of our charter, or by reason of any act of
God, war, terrorism, nationalization, expropriation, currency restrictions, work stoppage, strike,
civil unrest, revolutions, rebellions, explosions, computer failure or circumstance beyond any
such party’s direct and immediate control, the depositary,
 
we or any of our respective directors,
employees, agents or affiliates shall be prevented or delayed in performing, or shall be subject
to any civil or criminal penalty in connection with, any act which by the terms of the deposit
agreement or the ADRs it is provided shall be done or performed by it or them (including,
without limitation, voting pursuant to the terms of the ADRs); nor will the depositary, we or any
of our respective directors, employees, agents or affiliates incur any liability to you by reason of
any non-performance or delay, caused as aforesaid, in the performance of any act or things
which by the terms of the Deposit Agreement it is provided shall or may be done or performed
or of any exercise of, or failure to exercise, any discretion provided for under the deposit
agreement or any ADR (including, without limitation, any failure to determine that any
distribution or action may be lawful or reasonably practicable), or for any action or inaction by it
in reliance upon the advice of or information from legal counsel, accountants, any person
presenting ordinary shares for deposit, any ADR holder, or any other person believed by it to
be competent to give such advice or information.
Neither we nor the depositary nor any of our respective directors, officers, employees, agents
or affiliates assume any obligation or be subject to any liability except to perform its obligations
to the extent they are specifically provided under the deposit agreement or the ADRs without
gross negligence or willful misconduct. We, the depositary and its agents and may rely and
shall be protected in acting upon any written notice, request, direction, instruction or document
believed to be genuine and to have been signed, presented or given by the proper party or
parties.
The depositary and its agents have no obligation to appear in, prosecute or defend any action,
suit or other proceeding in respect of any deposited securities or the ADRs, and we and our
agents have no obligation to appear in, prosecute or defend any action, suit or other
proceeding in respect of any deposited securities or the ADRs, which in our opinion may
involve us in expense or liability, unless indemnity satisfactory to us against all expense
(including fees and disbursements of counsel) and liability is furnished as often as may be
required.
The depositary shall not be liable for the acts or omissions made by, or the insolvency of, any
securities depository, clearing agency or settlement system, and shall not have any liability for
the price received in connection with any sale of securities, the timing thereof or any delay in
action or omission to act, nor shall it be responsible for any error or delay in action, omission to
act, default or negligence on the part of the party so retained in connection with any such sale
or proposed sale. The depositary shall be under no obligation to inform registered holders of
ADRs or any other holders of an interest in any ADSs about the requirements of the laws, rules
or regulations or any changes therein or thereto of any country or jurisdiction or of any
governmental or regulatory authority or any securities exchange or market or automated
quotation system. The depositary and its agents will not be responsible for any failure to carry
out any instructions to vote any of the Deposited Securities, for the manner in which any such
vote is cast or for the effect of any such vote. The depositary may rely upon instructions from
us or our counsel in respect of any approval or license required for any currency conversion,
transfer or distribution. The depositary and its agents may own and deal in any class of our
securities and securities or our affiliates and in ADRs. Notwithstanding anything else contained
in the deposit agreement or any prior deposit agreement, the depositary shall have no liability
or responsibility under the deposit agreement, any ADR or any related agreement, for any
period prior to the effective date of the deposit agreement or for any act or omission of the
predecessor to the depositary or any of its agents (including the custodian as defined in the
prior deposit agreement), under or in connection with this deposit agreement, any ADRs or any
related agreement. Notwithstanding anything to the contrary set forth in the deposit agreement
or an ADR, the depositary and its agents may fully respond to any and all demands or requests
for information maintained by or on its behalf in connection with the deposit agreement, any
ADR holder or holders, any ADR or ADRs or otherwise related thereto to the extent such
information is requested or required by or pursuant to any lawful authority, including without
limitation laws, rules, regulations, administrative or judicial process, banking, securities or other
regulators.
None of us, the depositary or the custodian shall be liable for the failure by any registered
holder or beneficial owner of ADRs to obtain the benefits of credits or refunds of non-U.S. tax
paid against such holder’s or beneficial owner’s income tax liability. Neither we nor the
depositary shall incur any liability for any tax or tax consequences that may be incurred by
registered holders or beneficial owners of ADRs on account of their ownership or disposition of
the ADRs or ADSs.
The depositary shall not incur any liability for the content of any information submitted to it by
or on our behalf for distribution to the ADR holders or for any inaccuracy of any translation
thereof, for any investment risk associated with acquiring an interest in the deposited
securities, for the validity or worth of the deposited securities, for the credit-worthiness of any
third party, for allowing any rights to lapse upon the terms of the deposit agreement or for the
failure or timeliness of any notice from us. Notwithstanding anything set forth in the deposit
agreement to the contrary, the depositary and the custodian(s) may use third party delivery
services and providers of information regarding matters such as pricing, proxy voting,
corporate actions, class action litigation and other services in connection herewith and the
deposit agreement, and use local agents to provide extraordinary services such as attendance
at annual meetings of issuers of securities. Although the depositary and the custodian will use
reasonable care (and cause their agents to use reasonable care) in the selection and retention
of such third party providers and local agents, they will not be responsible for any errors or
omissions made by them in providing the relevant information or services. The depositary shall
not be liable for any acts or omissions made by a successor depositary whether in connection
with a previous act or omission of the depositary or in connection with any matter arising wholly
after the removal or resignation of the depositary, unless a liability is directly caused by the
previous gross negligence or willful misconduct of the depositary or its directors, officers,
employees, agents or affiliates acting in their capacities as such under the deposit agreement.
Neither we nor the depositary nor any of our respective agents shall be liable to registered
holders of ADRs or beneficial owners of interests in ADSs for any indirect, special, punitive or
consequential damages (including, without limitation, legal fees and expenses) or lost profits,
in each case of any form incurred by any person or entity, whether or not foreseeable and
regardless of the type of action in which such a claim may be brought.
The depositary shall not be responsible for, and shall incur no liability in connection with or
arising from any act or omission to act on the part of the custodian except to the extent that
any holder has incurred liability directly as a result of the custodian having (a) committed fraud
or willful misconduct in the provision of custodial services to the depositary or (b) failed to use
reasonable care in the provision of custodial services to the depositary as determined in
accordance with the standards prevailing in the jurisdiction in which the custodian is located.
As long as we or one of our affiliates is serving as the custodian with respect to the deposit
agreement we shall be solely liable for each and any act or failure to act on the part of the
custodian.
No provision of the deposit agreement or any ADR is intended to constitute a waiver or
limitation of any rights which an ADR holder or any person or entity having a beneficial
ownership interest in any ADSs may have under the Securities Act or the Securities Exchange
Act of 1934, to the extent applicable.
Governing Law, Submission to Jurisdiction and Waiver of Right to Trial
 
by Jury
The deposit agreement is governed by and construed in accordance with the laws of the State
of New York.
We have irrevocably agreed that any legal suit, action or proceeding against us brought by the
depositary or any holder, arising out of or based upon the deposit agreement or the
transactions contemplated thereby, may be instituted
 
in any state or federal court in New York,
New York,
 
and irrevocably waive any objection which we may now or hereafter have to the
laying of venue of any such proceeding, and irrevocably submit to the non-exclusive
jurisdiction of such courts in any such suit, action or proceeding. We have also irrevocably
agreed that any legal suit, action or proceeding against the depositary brought by us, arising
out of or based upon the deposit agreement or the transactions contemplated thereby, may
only be instituted in a state or federal court in New York, New York.
Each holder or beneficial owner of ADSs and each holder of interests therein, has irrevocably
agreed that any legal suit, action or proceeding against or involving us or the depositary,
arising out of or based on the deposit agreement, the ADSs, or the transactions contemplated
thereby, may only be instituted in a state or federal court in New York,
 
New York,
 
and each
such party has irrevocably waived any objection which it may now or hereafter have to the
laying of venue of any such proceeding, and irrevocably submits to the exclusive jurisdiction of
such courts in any such suit, action or proceeding.
Each party to the deposit agreement, including each holder and beneficial owner and/or holder
of interests in ADRs, irrevocably waives, to the fullest extent permitted by applicable law, any
right it may have to a trial by jury in any suit, action or proceeding against the depositary and/or
us directly or indirectly arising out of or relating to the ordinary shares or other deposited
securities, the ADSs or the ADRs, the deposit agreement or any transaction contemplated
therein, or the breach thereof, whether based on contract, tort, common law or any other
theory.
Appointment
In the deposit agreement, each registered holder of ADRs and each person holding an interest
in ADSs, upon acceptance of any ADSs (or any interest therein) issued in accordance with the
terms and conditions of the deposit agreement shall be deemed for all purposes to:
(a) be a party to and bound by the terms of the deposit agreement and the applicable ADR(s),
(b) appoint the depositary its attorney-in-fact, with full power to delegate, to act on its behalf
and to take any and all actions contemplated in the deposit agreement and the applicable
ADR(s), to adopt any and all procedures necessary to comply with applicable law and to take
such action as the depositary in its sole discretion may deem necessary or appropriate to carry
out the purposes of the deposit agreement and the applicable ADR(s), the taking of such
actions to be the conclusive determinant of the necessity and appropriateness thereof,
(c) acknowledge and agree that (i) nothing in the deposit agreement or any ADR shall give rise
to a partnership or joint venture among the parties thereto nor establish a fiduciary or similar
relationship among such parties, (ii) the depositary, its divisions, branches and affiliates, and
their respective agents, may from time to time be in the possession of non-public information
about Equinor, ADR holders, owners of ADSs and/or their respective affiliates, (iii) the
depositary and its divisions, branches and affiliates may at any time have multiple banking
relationships with Equinor, ADR holders, owners of ADSs and/or the affiliates of any of them,
(iv) the depositary and its divisions, branches and affiliates may,
 
from time to time, be engaged
in transactions in which parties adverse to Equinor or the Holders or owners of ADSs may
have interests, (v) nothing contained in the Deposit Agreement or any ADR(s) shall (A)
preclude the Depositary or any of its divisions, branches or affiliates from engaging in such
transactions or establishing or maintaining such relationships, or (B) obligate the Depositary or
any of its divisions, branches or affiliates to disclose such transactions or relationships or to
account for any profit made or payment received in such transactions or relationships, and (vi)
the Depositary shall not be deemed to have knowledge of any information held by any branch,
division or affiliate of the Depositary.
 
exhibit25p1i0
AMENDED AND RESTATED
 
AGENCY AGREEMENT
9 MAY 2022
EQUINOR ASA
as
Issuer
and
EQUINOR ENERGY AS
as Guarantor
THE BANK OF NEW
 
YORK MELLON, LONDON
 
BRANCH
as
Agent
and
THE BANK OF NEW
 
YORK MELLON SA/NV, LUXEMBOURG BRANCH
as Paying Agent
in respect of a
€20,000,000,000
EURO MEDIUM TERM
 
NOTE PROGRAMME
Allen & Overy LLP
0010155-0003327 UKO2:
 
2004375908.9
CONTENTS
Clause
 
Page
1.
2.
3.
4.
5.
6.
7.
8.
9.
10.
11.
12.
13.
14.
15.
16.
17.
18.
19.
20.
21.
22.
23.
24.
25.
26.
27.
28.
29.
30.
31.
32.
33.
34.
35.
Schedule
 
Page
1.
 
Terms
 
and Conditions of the Notes
 
other than VPS Notes
 
................................
 
..................
 
29
2.
 
Forms of Global and Definitive
 
Notes, Coupons and
 
Talons ................................
 
...............
 
78
Part 1
 
Form of Temporary Global Note
 
................................
 
................................
 
........
 
78
Part 2
 
Form of Permanent Global
 
Note
 
................................
 
................................
 
........
 
86
Part 3
 
Form of Definitive Note
 
................................
 
................................
 
......................
 
94
3.
 
Form of Deed of Covenant
 
................................
 
................................
 
................................ 100
4.
 
Provisions for Meetings
 
of Noteholders
 
................................
 
................................
 
.............
 
103
5.
 
Form of Put Notice
 
................................
 
................................
 
................................
 
............
 
109
6.
 
Form of Deed Poll
 
................................
 
................................
 
................................
 
.............
 
111
7.
 
Form of Issuer – ICSDs
 
Agreement
 
................................
 
................................
 
.................. 117
8.
 
Additional Duties of the Agent
 
................................
 
................................
 
........................... 121
Appendix
1.
 
Form of Calculation Agency
 
Agreement
 
................................
 
................................
 
............
 
124
4
AMENDED AND RESTATED AGENCY AGREEMENT
in respect of a
€20,000,000,000
EURO MEDIUM TERM
 
NOTE PROGRAMME
THIS AGREEMENT
is made on 9 May
 
2022
BETWEEN
:
(1)
EQUINOR ASA
of Forusbeen 50, N-4035 Stavanger, Norway in its capacity as an issuer of
Notes under the Programme (the
Issuer
);
(2)
EQUINOR ENERGY AS
of Forusbeen 50, N-4035 Stavanger, Norway
 
(the
Guarantor
);
(3)
THE
 
BANK
 
OF
 
NEW
 
YORK
 
MELLON,
 
LONDON
 
BRANCH
of
 
One
 
Canada
 
Square,
London
 
E14
 
5AL,
 
United
 
Kingdom
 
(the
Agent
,
 
which
 
expression
 
shall
 
include
 
any
successor agent appointed in accordance with clause
); and
(4)
THE
 
BANK
 
OF
 
NEW
 
YORK
 
MELLON
 
SA/NV,
 
LUXEMBOURG
 
BRANCH
of
 
Vertigo
Building -
 
Polaris, 2-4
 
rue, Eugène
 
Ruppert, L-2453
 
Luxembourg (together
 
with the
 
Agent,
the
Paying
 
Agents
,
 
which
 
expression
 
shall
 
include
 
any
 
additional
 
or
 
successor
 
paying
agent appointed
 
in accordance with clause
 
and
Paying Agent
shall mean any of the
Paying Agents).
WHEREAS
:
(A)
 
The
 
parties
 
hereto
 
entered
 
into
 
an
 
amended
 
and
 
restated
 
Agency
 
Agreement
 
(the
Previous
 
Agency
 
Agreement
) dated
 
13 May
 
2020 in
 
respect of
 
a €20,000,000,000
 
Euro
Medium Term
 
Note Programme (the
Programme
).
(B)
 
The parties hereto wish
 
to make certain modifications
 
to the Previous Agency
 
Agreement.
(C)
 
The
 
Issuer
 
and
 
the
 
Guarantor
 
have
 
entered
 
into
 
an
 
amended
 
and
 
restated
 
programme
agreement
 
(as
 
modified
 
and/or
 
restated
 
and/or
 
supplemented
 
from
 
time
 
to
 
time,
 
the
Programme
 
Agreement
)
 
dated
 
9
 
May
 
2022
 
with
 
the
 
Dealers
 
named
 
therein
 
pursuant
 
to
which the Issuer may issue
 
Euro Medium Term
 
Notes (the
Notes
) in an aggregate nominal
amount
 
of
 
up
 
to
 
€20,000,000,000
 
(or
 
its
 
equivalent
 
in
 
other
 
currencies)
 
under
 
the
Programme.
(D)
 
Each
 
issue
 
of
 
Notes
 
(other
 
than
 
VPS
 
Notes)
 
will
 
be
 
initially
 
represented
 
by
 
a
 
temporary
global Note
 
exchangeable in whole
 
or in
 
part for definitive
 
Notes or for
 
a permanent global
Note which will be exchangeable as described therein for definitive
 
Notes.
IT IS HEREBY AGREED
as follows:
1.
 
DEFINITIONS AND INTERPRETATION
1.1
 
Terms
 
and expressions
 
defined in
 
the Programme
 
Agreement or
 
the Notes
 
or used
 
in the
applicable Final Terms
 
shall have the same meanings
 
in this Agreement, except
 
where the
context requires otherwise or unless otherwise stated.
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1.2
 
Without prejudice to the
 
foregoing:
Authorised Person
means any person who is designated in writing by the Issuer from
 
time
to time
 
to give Instructions to the Agent under the terms of this Agreement;
CGN
means
 
a
 
Temporary
 
Global
 
Note
 
in
 
the
 
form
 
set
 
out
 
in
 
of
 
or
 
a
Permanent Global Note in the form set out in
 
of
, in either case where the
applicable Final Terms specify that the Notes are not in New Global Note form;
Clearstream, Luxembourg
means Clearstream
 
Banking S.A.;
Code
means the U.S. Internal Revenue Code
 
of 1986, as amended;
Conditions
means,
 
in
 
relation
 
to
 
the
 
Notes
 
of
 
any
 
Series,
 
the
 
terms
 
and
 
conditions
endorsed on
 
or incorporated
 
by reference
 
into the
 
Note or
 
Notes constituting
 
such Series,
such terms
 
and conditions
 
being in
 
or substantially
 
in the
 
form set
 
out in
 
Schedule 1
 
or in
such other form,
 
having regard to
 
the terms of
 
the Notes of
 
the relevant Series,
 
as may be
agreed
 
between the
 
Issuer,
 
the
 
Agent
 
and the
 
relevant
 
Dealer
 
as
 
completed
 
by the
 
Final
Terms
 
applicable to the Notes of the relevant Series;
Coupon
means
 
an
 
interest
 
coupon
 
appertaining
 
to
 
a
 
Definitive
 
Note
 
(other
 
than
 
a
 
Zero
Coupon Note), such coupon being:
(a)
 
if appertaining
 
to a
 
Fixed Rate
 
Note, in
 
the form
 
or substantially
 
in the
 
form set
 
out
in
A of
 
or in
 
such other
 
form, having
 
regard to
 
the terms
 
of issue
of the Notes of the relevant Series, as may be agreed between the Issuer, the Agent
and the relevant Dealer; or
(b)
 
if
 
appertaining to
 
a
 
Floating Rate
 
Note,
 
in
 
the
 
form
 
or
 
substantially in
 
the
 
form
 
set
out
 
in
B
 
of
 
or
 
in
 
such other
 
form,
 
having
 
regard to
 
the
 
terms
 
of
issue of the Notes of the relevant Series,
 
as may be agreed between the Issuer,
 
the
Agent and the relevant Dealer; or
(c)
 
if appertaining to a Definitive Note which
 
is neither a Fixed Rate Note nor a
 
Floating
Rate Note,
 
in such
 
form as
 
may be
 
agreed between
 
the Issuer,
 
the Agent
 
and the
relevant Dealer,
and includes, where applicable, the Talon(s)
 
appertaining thereto and any replacements for
Coupons and Talons issued pursuant to Condition 9;
Couponholders
means
 
the
 
several
 
persons
 
who
 
are
 
for
 
the
 
time
 
being
 
holders
 
of
 
the
Coupons
 
and
 
shall,
 
unless
 
the
 
context
 
otherwise
 
requires,
 
include
 
the
 
holders
 
of
 
the
Talons;
Deed
 
of
 
Covenant
means
 
the
 
deed
 
of
 
covenant,
 
as
 
modified
 
and/or
 
restated
 
and/or
supplemented
 
from
 
time
 
to
 
time,
 
dated
 
13
 
May
 
2020,
 
substantially
 
in
 
the
 
form
 
set
 
out
 
in
,
 
executed
 
as
 
a
 
deed
 
by
 
the
 
Issuer
 
in
 
favour
 
of
 
certain
 
accountholders
 
with
Euroclear and Clearstream, Luxembourg;
Deed
 
Poll
means any
 
Deed Poll as
 
defined in
 
Condition 14
 
the form
 
of which is
 
set out
 
in
 
hereto;
Definitive Note
means a definitive Note issued or, as the case may require,
 
to be issued by
the
 
Issuer
 
in
 
accordance
 
with
 
the
 
provisions
 
of
 
the
 
Programme
 
Agreement
 
or
 
any
 
other
agreement between the Issuer
 
and the relevant Dealer
 
in exchange for
 
either a Temporary
Global
 
Note
 
or
 
a
 
Permanent
 
Global
 
Note
 
(all
 
as
 
indicated
 
in
 
the
 
applicable Final
 
Terms),
0010155-0003327 UKO2:
 
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such
 
definitive
 
Note
 
being
 
in
 
the
 
form
 
or
 
substantially
 
in
 
the
 
form
 
set
 
out
 
in
 
of
 
with
 
such
 
modifications
 
(if
 
any)
 
as
 
may
 
be
 
agreed
 
between
 
the
 
Issuer,
 
the
Agent
 
and the
 
relevant
 
Dealer
 
and
 
having the
 
Conditions endorsed
0010155-0003327 UKO2:
 
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thereon or,
 
if permitted by the
 
relevant authority or authorities,
 
incorporating the Conditions
by
 
reference
 
and
 
having
 
the
 
applicable
 
Final
 
Terms
 
(or
 
the
 
relevant
 
provisions
 
thereof)
either
 
endorsed
 
thereon
 
or
 
attached
 
thereto
 
and
 
(except
 
in
 
the
 
case
 
of
 
a
 
Zero
 
Coupon
Note) having Coupons and, where appropriate, Talons attached thereto on issue;
Distribution
 
Compliance
 
Period
has
 
the
 
meaning
 
given
 
to
 
such
 
term
 
in
 
Regulation
 
S
under the Securities Act;
Euroclear
means Euroclear Bank SA/NV;
Eurosystem-eligible NGN
means an NGN which is intended to be held
 
in a manner which
would allow Eurosystem eligibility, as stated in the applicable Final Terms;
FATCA
 
Withholding
means
 
any
 
withholding
 
or
 
deduction
 
required
 
pursuant
 
to
 
an
agreement
 
described
 
in
 
Section
 
1471(b)
 
of
 
the
 
Code
 
or
 
otherwise
 
imposed
 
pursuant
 
to
Sections
 
1471
 
through
 
1474
 
of
 
the
 
Code
 
(or
 
any
 
regulations
 
thereunder
 
or
 
official
interpretations thereof)
 
or an
 
intergovernmental agreement between
 
the United
 
States and
another jurisdiction facilitating the implementation thereof (or any law implementing such an
intergovernmental agreement);
Fixed
 
Rate
 
Note
means a
 
Note on
 
which interest
 
is calculated
 
at
 
a fixed
 
rate
 
payable in
arrear on
 
a fixed
 
date or
 
dates in
 
each year
 
and on
 
redemption or
 
on such
 
other dates
 
as
may be
 
agreed between
 
the Issuer
 
and the
 
relevant Dealer
 
(as indicated
 
in the
 
applicable
Final Terms);
Floating Rate
 
Note
means a Note on which interest is calculated at
 
a floating rate payable
in respect of
 
such period or
 
on such date(s) as
 
may be agreed
 
between the Issuer and
 
the
relevant Dealer (as indicated in the applicable Final Terms);
Global Note
means a Temporary Global Note and/or a Permanent
 
Global Note, as
applicable;
Grandfathering
 
Date
means
 
the
 
date
 
that
 
is
 
six
 
months
 
after
 
the
 
date
 
on
 
which
 
final
regulations defining
 
the term
 
“foreign passthru
 
payment” are
 
published in
 
the U.S.
 
Federal
Register;
Guarantee
means
 
the
 
Deed
 
of
 
Guarantee,
 
as
 
modified
 
and/or
 
restated
 
and/or
supplemented from
 
time to
 
time, executed
 
by the
 
Guarantor on
 
13 May
 
2020 in
 
respect of
the Programme;
Instructions
means
 
any
 
written
 
notices,
 
directions
 
or
 
instructions
 
received
 
by
 
the
 
Agent
from
 
an
 
Authorised
 
Person
 
or
 
from
 
a
 
person
 
reasonably
 
believed
 
by
 
the
 
Agent
 
to
 
be
 
an
Authorised Person;
Interest
 
Commencement
 
Date
means,
 
in
 
the
 
case
 
of
 
interest-bearing
 
Notes,
 
the
 
date
specified in the applicable Final Terms
 
from (and including) which such Notes bear interest,
which may or may not be the Issue Date;
Issue Date
means the date of issue
 
and purchase of a Note,
 
in each case pursuant to
 
and
in accordance with
 
the Programme Agreement or
 
any other agreement between
 
the Issuer
and the relevant Dealer, being in the case of any Permanent Global Note or Definitive Note,
the same date as the date of issue of the Temporary Global Note which initially represented
such Note;
Issue Price
means the price,
 
generally expressed as
 
a percentage of
 
the nominal amount
of the
 
Notes, at which the Notes will be issued;
0010155-0003327 UKO2:
 
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Maturity Date
means, in relation to
 
a Note, the date on which
 
it is expressed to be
redeemable;
0010155-0003327 UKO2:
 
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NGN
means
 
a
 
Temporary
 
Global
 
Note
 
in
 
the
 
form
 
set
 
out
 
in
 
of
 
or
 
a
Permanent Global Note in the form set out in
 
of
, in either case where the
applicable Final Terms specify that the Notes are in New Global Note form;
Note
means
 
a
 
note
 
denominated
 
in
 
Australian Dollars,
 
Canadian
 
Dollars,
 
Danish
 
Kroner,
Euro,
 
Hong Kong
 
Dollars, Japanese
 
Yen,
 
New Zealand
 
Dollars, Norwegian
 
Kroner,
 
South
African Rand, Sterling,
 
Swedish Kronor,
 
Swiss Francs, U.S.
 
Dollars or such
 
other currency
or currencies as may be agreed between the Issuer and the relevant Dealer issued or to be
issued
 
by
 
the
 
Issuer
 
pursuant
 
to
 
the
 
Programme
 
Agreement
 
or
 
any
 
other
 
agreement
between the Issuer and the
 
relevant Dealer and which shall
 
initially be represented by,
 
and
comprised in,
 
a Temporary
 
Global Note
 
which may
 
(in accordance
 
with the
 
terms of
 
such
Temporary
 
Global
 
Note)
 
be
 
exchanged for
 
either
 
Definitive
 
Notes
 
or
 
a
 
Permanent
 
Global
Note which
 
Permanent Global Note
 
may (in
 
accordance with the
 
terms of such
 
Permanent
Global
 
Note)
 
in
 
turn
 
be
 
exchanged
 
for
 
Definitive
 
Notes
 
(all
 
as
 
indicated
 
in
 
the
 
applicable
Final Terms)
 
and includes any replacements for a Note issued pursuant
 
to Condition 9;
Noteholders
means the
 
several persons
 
who are
 
for the
 
time
 
being holders
 
of the
 
Notes
save
 
that,
 
in
 
respect
 
of
 
the
 
Notes
 
of
 
any
 
Series,
 
for
 
so
 
long
 
as
 
such
 
Notes
 
or
 
any
 
part
thereof
 
are
 
represented
 
by
 
a
 
Global
 
Note
 
held
 
on
 
behalf
 
of
 
Euroclear
 
and/or
 
of
Clearstream,
 
Luxembourg,
 
each
 
person
 
(other
 
than
 
Euroclear
 
or
 
Clearstream,
Luxembourg) who is for the time being shown in the records of Euroclear or of Clearstream,
Luxembourg as
 
the
 
holder of
 
a
 
particular nominal
 
amount
 
of
 
the
 
Notes of
 
such Series
 
(in
which
 
regard
 
any
 
certificate
 
or
 
other
 
document
 
issued
 
by
 
Euroclear
 
or
 
Clearstream,
Luxembourg as to the nominal amount of such Notes standing to the account of any person
shall be conclusive and binding
 
for all purposes save
 
in the case of manifest
 
error) shall be
treated by the
 
Issuer, the
 
Agent and any other
 
Paying Agent as
 
the holder of
 
such nominal
amount of such Notes for all purposes other than with respect to the payment of principal or
interest
 
on such
 
Notes, for
 
which purpose
 
the
 
bearer of
 
the relevant
 
Global
 
Note shall
 
be
treated by the
 
Issuer, the
 
Agent and any other
 
Paying Agent as the
 
holder of such
 
nominal
amount
 
of such
 
Notes in
 
accordance with
 
and subject
 
to
 
the terms
 
of the
 
relevant Global
Note and
 
the
 
expressions
Noteholder
,
holder
 
of
 
Notes
and related
 
expressions shall
 
be
construed accordingly;
outstanding
means, in
 
relation to the
 
Notes of any
 
Series, all the
 
Notes issued other
 
than
(a) those which
 
have been redeemed in
 
full in accordance
 
with the Conditions, (b)
 
those in
respect
 
of
 
which the
 
date
 
for
 
redemption
 
in
 
accordance
 
with the
 
Conditions has
 
occurred
and the
 
redemption moneys
 
wherefor (including
 
all interest
 
(if any)
 
accrued thereon
 
to the
date for
 
such redemption and
 
any interest (if
 
any) payable
 
under the
 
Conditions after such
date) have
 
been duly
 
paid to the
 
Agent as
 
provided herein (and,
 
where appropriate, notice
has been
 
given to the
 
Noteholders of the
 
relevant Series in
 
accordance with Condition
 
12)
and
 
remain
 
available
 
for
 
payment
 
of
 
the
 
relevant
 
Notes
 
and/or
 
Coupons,
 
(c)
 
those
 
which
have
 
become
 
void
 
under
 
the
 
Conditions,
 
(d)
 
those
 
which
 
have
 
been
 
purchased
 
and
cancelled as
 
provided in
 
the Conditions,
 
(e) those
 
mutilated or
 
defaced Notes
 
which have
been
 
surrendered
 
in
 
exchange
 
for
 
replacement
 
Notes
 
pursuant
 
to
 
the
 
Conditions,
 
(f)
 
(for
the purpose
 
only of
 
determining how
 
many Notes
 
are outstanding and
 
without prejudice to
their
 
status
 
for
 
any
 
other
 
purpose)
 
those
 
Notes
 
alleged
 
to
 
have
 
been
 
lost,
 
stolen
 
or
destroyed
 
and
 
in
 
respect
 
of
 
which
 
replacement
 
Notes
 
have
 
been
 
issued
 
pursuant
 
to
 
the
Conditions,
 
(g)
 
Temporary
 
Global
 
Notes
 
to
 
the
 
extent
 
that
 
they
 
shall
 
have
 
been
 
duly
exchanged
 
for
 
Permanent
 
Global
 
Notes
 
and/or
 
Definitive
 
Notes
 
and
 
Permanent
 
Global
Notes to
 
the extent
 
that they
 
shall have
 
been duly
 
exchanged for
 
Definitive Notes,
 
in each
case
 
pursuant
 
to
 
their
 
respective
 
provisions
 
and
 
(h)
 
Temporary
 
Global
 
Notes
 
and
Permanent Global Notes which have become
 
void in accordance with their
 
terms (provided
that
 
at the
 
Relevant Time
 
(as
 
defined in
 
the
 
Deed of
 
Covenant) the
 
Underlying Notes
 
(as
defined in the Deed of Covenant) will be deemed to be still outstanding)
 
and,
0010155-0003327 UKO2:
 
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PROVIDED THAT for each of the
 
following purposes, namely:
0010155-0003327 UKO2:
 
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(i)
 
the
 
right
 
to
 
attend
 
and
 
vote
 
at
 
any
 
meeting
 
of
 
the
 
Noteholders
 
or
 
any
 
of
 
them,
passing
 
an
 
Extraordinary
 
Resolution
 
(as
 
defined
 
in
)
 
in
 
writing
 
or
 
an
Extraordinary
 
Resolution by
 
way
 
of
 
electronic
 
consents
 
given
 
through
 
the
 
relevant
clearing systems as envisaged by
; and
(ii)
 
the determination
 
of how
 
many and
 
which Notes are
 
for the
 
time being
 
outstanding
for the purposes of paragraphs
 
and
 
of
 
hereto,
those
 
Notes
 
(if
 
any)
 
which
 
are
 
for
 
the
 
time
 
being
 
held
 
by
 
any
 
person
 
(including
 
but
 
not
limited
 
to
 
the
 
Issuer
 
or
 
any
 
of
 
its
 
Subsidiaries)
 
for
 
the
 
benefit
 
of
 
the
 
Issuer
 
or
 
any
 
of
 
its
Subsidiaries
 
shall
 
(unless
 
and
 
until
 
ceasing
 
to
 
be
 
so
 
held)
 
be
 
deemed
 
not
 
to
 
be
outstanding;
Participating
 
FFI
means
 
a
 
“participating
 
FFI”
 
as
 
defined
 
in
 
US
 
Treasury
 
Regulations
Section
 
1.1471-1(b)(91) (or
 
any successor
 
provision) or
 
any other
 
entity whose
 
payments
are subject to FATCA
 
Withholding;
Permanent
 
Global
 
Note
means a
 
global note
 
in
 
the
 
form
 
or
 
substantially in
 
the
 
form
 
set
out
 
in
 
of
 
together with
 
the copy
 
of the
 
applicable Final
 
Terms
 
attached
thereto
 
with
 
such
 
modifications
 
(if
 
any)
 
as
 
may
 
be
 
agreed
 
between
 
the
 
Issuer,
 
the
 
Agent
and the relevant Dealer,
 
comprising some or all
 
of the Notes of
 
the same Series, issued
 
by
the
 
Issuer
 
pursuant
 
to
 
the
 
Programme
 
Agreement
 
or
 
any
 
other
 
agreement
 
between
 
the
Issuer and
 
the relevant
 
Dealer in
 
exchange for
 
the whole
 
or part
 
of any
 
Temporary
 
Global
Note issued in respect of such Notes;
Put Notice
means a notice in the
 
form set out in
Series
means a Tranche of
 
the Notes together with any further Tranche
 
or Tranches of the
Notes which are (a)
 
expressed to be consoli
dated
and form a
 
single series and (b)
 
identical
in
 
all
 
respects
 
(including
 
as
 
to
 
listing)
 
except
 
for
 
their
 
respective
 
Issue
 
Dates,
 
Interest
Commencement
 
Dates
 
and/or
 
Issue
 
Prices
 
and
 
the
 
expressions
Notes
 
of
 
the
 
relevant
Series
and
holders
 
of
 
Notes
 
of
 
the
 
relevant
 
Series
and
 
related
 
expressions
 
shall
 
be
construed accordingly;
Talons
means the talons (if any) appertaining to, and exchangeable in accordance with the
provisions
 
therein
 
contained
 
for
 
further
 
Coupons
 
appertaining
 
to,
 
a
 
Definitive
 
Note
 
(other
than a
 
Zero Coupon Note), such talons being in the form or substantially in the form set out
in
 
of
 
or
 
in
 
such
 
other
 
form
 
as may
 
be
 
agreed
 
between the
 
Issuer,
 
the
Agent and the relevant Dealer and includes any replacements for Talons issued pursuant to
Condition 9;
Temporary
 
Global
 
Note
means
 
a
 
global note
 
in
 
the
 
form
 
or
 
substantially in
 
the
 
form
 
set
out
 
in
 
of
 
together with
 
the
 
copy of
 
the
 
applicable Final
 
Terms
 
attached
thereto
 
with
 
such
 
modifications
 
(if
 
any)
 
as
 
may
 
be
 
agreed
 
between
 
the
 
Issuer,
 
the
 
Agent
and the relevant Dealer,
 
comprising some or all
 
of the Notes of
 
the same Series, issued
 
by
the
 
Issuer
 
pursuant
 
to
 
the
 
Programme
 
Agreement
 
or
 
any
 
other
 
agreement
 
between
 
the
Issuer and the relevant Dealer;
Tranche
means all Notes with
 
the same Issue Date and subject
 
to the same Final
 
Terms;
and
Zero Coupon Note
means a Note on which no
 
interest is payable.
1.3
 
(a)
 
Words
 
denoting
 
the
 
singular
 
number
 
only
 
shall
 
include
 
the
 
plural
 
number
 
also
and
vice versa
;
0010155-0003327 UKO2:
 
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(b)
 
words denoting one gender
 
only shall include the
 
other gender; and
(c)
 
words denoting persons only
 
shall include firms and
 
corporations and vice versa.
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1.4
 
All
 
references
 
in
 
this
 
Agreement to
 
costs
 
or
 
charges
 
or
 
expenses
 
shall
 
include any
 
value
added
 
tax
 
or
 
similar
 
tax
 
charged
 
or
 
chargeable
 
in
 
respect
 
thereof
 
to
 
the
 
extent
 
not
recoverable as an input.
1.5
 
All references in the Agreement to "the Guarantor" shall
 
be deemed to be deleted in relation
to Notes that do not have the benefit of the Guarantee.
1.6
 
For the
 
purposes of this
 
Agreement, the
 
Notes of each
 
Series shall form
 
a separate
 
series
of Notes
 
and the provisions
 
of this Agreement
 
shall apply
mutatis mutandis
separately and
independently to
 
the
 
Notes of
 
each
 
Series
 
and
 
in this
 
Agreement the
 
expressions
Notes
,
Noteholders
,
Coupons
,
Couponholders
and
Talons
shall be construed accordingly.
1.7
 
All references
 
in this
 
Agreement to
 
principal and/or interest
 
or both
 
in respect
 
of the
 
Notes
or to
 
any moneys
 
payable by
 
the Issuer
 
under this
 
Agreement shall
 
have the
 
meaning set
out in Condition 4(f).
1.8
 
All references in this Agreement to the
relevant currency
shall be construed as references
to the currency in which the relevant Notes and/or Coupons are denominated.
1.9
 
In
 
this
 
Agreement,
 
clause
 
headings
 
are
 
inserted
 
for
 
convenience
 
and
 
ease
 
of
 
reference
only
 
and
 
shall
 
not
 
affect
 
the
 
interpretation
 
of
 
this
 
Agreement.
 
All
 
references
 
in
 
this
Agreement to the provisions of any statute shall be
 
deemed to be references to that statute
as
 
from
 
time
 
to
 
time
 
modified,
 
extended,
 
amended
 
or
 
re-enacted
 
or
 
to
 
any
 
statutory
instrument, order or regulation made thereunder or under such re-enactment.
1.10
 
All references in this Agreement
 
to an agreement, instrument or
 
other document (including,
without limitation,
 
this Agreement,
 
the
 
Programme Agreement,
 
the Deed
 
of
 
Covenant, the
Guarantee,
 
the
 
Procedures
 
Memorandum,
 
the
 
Notes
 
and
 
any
 
Conditions
 
appertaining
thereto)
 
shall be
 
construed as
 
a reference
 
to
 
that
 
agreement, instrument
 
or document
 
as
the same may be amended, modified,
 
varied or supplemented from time to time.
1.11
 
Any
 
references
 
herein
 
to
 
Euroclear
 
and/or
 
Clearstream,
 
Luxembourg
 
shall,
 
whenever
 
the
context
 
so
 
permits,
 
be
 
deemed
 
to
 
include
 
a
 
reference
 
to
 
any
 
additional
 
or
 
alternative
clearance system approved by the Issuer
 
and the Agent or as
 
otherwise specified in Part B
of the applied Final Terms.
1.12
 
All
 
references
 
to
 
the
records
of
 
Euroclear
 
and
 
Clearstream,
 
Luxembourg
 
shall
 
be
 
to
 
the
records that each of Euroclear and Clearstream, Luxembourg holds for its
 
customers which
reflect the amount of such customer's interest in the Notes.
1.13
 
As used herein, in relation to
 
any Notes which are to have
 
a "listing" or be "listed" (i)
 
on the
London
 
Stock
 
Exchange,
listing
and
listed
shall
 
be
 
construed
 
to
 
mean
 
that
 
such
 
Notes
have
 
been
 
admitted
 
to
 
the
 
Official
 
List
 
and
 
admitted
 
to
 
trading
 
on
 
the
 
London
 
Stock
Exchange's
 
main market and (ii) on any
 
European Economic Area Stock Exchange,
listing
and
listed
shall be
 
construed to
 
mean that
 
that Notes
 
have been
 
admitted to
 
trading on
 
a
market within that jurisdiction which is a regulated market for the purposes of the Markets in
Financial Instruments Directive (Directive 2014/65/EU, as amended).
1.14
 
This Agreement does not apply
 
to the VPS Notes.
1.15
 
With effect from the
 
date hereof, the provisions of the
 
Previous Agency Agreement shall be
amended and
 
restated and
 
shall take
 
effect
 
in the
 
form
 
set
 
out in
 
this Agency
 
Agreement
and all references to
 
the
Agency Agreement
,
this Agency
 
Agreement
,
this Agreement
,
hereof
,
hereunder
and
 
expressions
 
of
 
similar
 
import
 
in
 
this
 
Agency
 
Agreement
 
shall
 
be
construed as
 
references to
 
the Previous
 
Agency Agreement
 
as so
 
amended and
 
restated.
Any
 
Notes
 
issued
 
on
 
or
 
after
 
the
 
date
 
hereof
 
shall
 
be
 
issued
 
pursuant
 
to
 
this
 
Agency
0010155-0003327 UKO2:
 
2004375908.9
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Agreement.
 
This does not affect any Notes issued prior to the date of this Agreement.
0010155-0003327 UKO2:
 
2004375908.9
15
2.
 
APPOINTMENT OF AGENT
 
AND PAYING
 
AGENTS
2.1
 
The Agent
 
is hereby
 
appointed, and the
 
Agent hereby agrees
 
to act
 
as issuing and
 
paying
agent of the
 
Issuer and the
 
Guarantor upon the
 
terms and subject to
 
the conditions set
 
out
below, for the purposes of,
inter alia
:
(a)
 
completing, authenticating and delivering Global
 
Notes and (if required)
 
completing,
authenticating and delivering Definitive Notes;
(b)
 
giving
 
effectuation
 
instructions
 
in
 
respect
 
of
 
each
 
Global
 
Note
 
which
 
is
 
a
Eurosystem-
 
eligible NGN;
(c)
 
exchanging
 
Temporary
 
Global
 
Notes
 
for
 
Permanent
 
Global
 
Notes
 
or
 
Definitive
Notes,
 
as
 
the
 
case
 
may
 
be,
 
in
 
accordance
 
with
 
the
 
terms
 
of
 
Temporary
 
Global
Notes
 
and,
 
in
 
respect
 
of
 
any
 
such
 
exchange,
 
(i)
 
making
 
all
 
notations
 
on
 
Global
Notes which
 
are CGNs
 
as required
 
by their
 
terms and
 
(ii) instructing
 
Euroclear and
Clearstream, Luxembourg to
 
make appropriate entries
 
in their records
 
in respect
 
of
all Global Notes which are NGNs;
(d)
 
exchanging
 
Permanent
 
Global
 
Notes
 
for
 
Definitive
 
Notes
 
in
 
accordance
 
with
 
the
terms
 
of
 
such
 
Permanent
 
Global
 
Notes
 
and,
 
in
 
respect
 
of
 
any
 
such
 
exchange,
 
(i)
making
 
all
 
notations
 
on
 
Permanent
 
Global
 
Notes
 
which
 
are
 
CGNs
 
as
 
required
 
by
their
 
terms
 
and
 
(ii)
 
instructing
 
Euroclear
 
and
 
Clearstream,
 
Luxembourg
 
to
 
make
appropriate entries
 
in their
 
records in
 
respect of
 
all Permanent
 
Global Notes
 
which
are NGNs;
(e)
 
paying sums due on Global Notes and Definitive Notes and Coupons and
 
instructing
Euroclear
 
and
 
Clearstream,
 
Luxembourg
 
to
 
make
 
appropriate
 
entries
 
in
 
their
records in respect of all Global Notes which are NGNs;
(f)
 
exchanging Talons for Coupons in accordance with the
 
Conditions;
(g)
 
arranging on behalf
 
of the Issuer or,
 
as the case may
 
be, the Guarantor,
 
for notices
to be communicated to the Noteholders;
(h)
 
ensuring
 
that
 
all
 
necessary
 
action
 
is
 
taken
 
to
 
comply
 
with
 
any
 
reporting
requirements of any competent authority in respect
 
of any relevant currency as may
be
 
in
 
force
 
from
 
time
 
to
 
time
 
with
 
respect
 
to
 
the
 
Notes
 
to
 
be
 
issued
 
under
 
the
Programme;
(i)
 
subject
 
to
 
the
 
Procedures
 
Memorandum,
 
submitting
 
to
 
the
 
relevant
 
authority
 
or
authorities such number of copies of each Final Terms
 
which relates to Notes which
are to be listed as the relevant authority or authorities may reasonably
 
require;
(j)
 
acting
 
as
 
Calculation
 
Agent
 
in
 
respect
 
of
 
Notes
 
where
 
named
 
as
 
such
 
in
 
the
relevant Final Terms; and
(k)
 
performing
 
all
 
other
 
obligations and
 
duties
 
imposed
 
upon
 
it
 
by
 
the
 
Conditions and
this Agreement.
2.2
 
Each Paying
 
Agent is
 
hereby appointed
 
as paying
 
agent of
 
the Issuer
 
and the
 
Guarantor,
upon
 
the
 
terms
 
and
 
subject
 
to
 
the
 
conditions
 
set
 
out
 
below,
 
for
 
the
 
purposes
 
of
 
paying
sums
 
due
 
on
 
Notes
 
and
 
Coupons
 
and
 
of
 
performing
 
all
 
other
 
obligations
 
and
 
duties
imposed
 
upon
 
it
 
by
 
the
 
Conditions
 
and
 
this
 
Agreement.
 
The
 
obligations
 
of
 
the
 
Paying
Agents under this Agreement shall be several and
 
not joint.
0010155-0003327 UKO2:
 
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2.3
 
In
 
relation
 
to
 
each
 
issue
 
of
 
Eurosystem-eligible
 
NGNs,
 
the
 
Issuer
 
hereby
 
authorises
 
and
instructs
 
the
 
Agent
 
to
 
elect
 
Euroclear
 
and/or
 
Clearstream,
 
Luxembourg
 
as
 
common
safekeeper.
 
From time
 
to
 
time, the
 
Issuer
 
and
 
the
 
Agent may
 
agree to
 
vary
 
this
 
election.
The
 
Issuer
 
acknowledges
 
that
 
any
 
such
 
election
 
is
 
subject
 
to
 
the
 
right
 
of
 
Euroclear
 
and
Clearstream,
 
Luxembourg
 
to
 
jointly
 
determine
 
that
 
the
 
other
 
shall
 
act
 
as
 
common
safekeeper in relation to any such issue and agrees that no liability shall attach to the Agent
in respect of any such election made by it.
3.
 
ISSUE OF TEMPORARY GLOBAL NOTES
3.1
 
Subject to subclause
 
below, following receipt
 
of a faxed copy
 
of the Final Terms
 
signed
by
 
the
 
Issuer
 
and
 
the
 
Guarantor,
 
the
 
Issuer
 
hereby
 
authorises
 
the
 
Agent
 
and
 
the
 
Agent
hereby agrees to take the steps required of the Agent in the Procedures Memorandum.
 
For
this purpose the Agent will,
inter alia,
on behalf of the Issuer:
(a)
 
prepare a Temporary
 
Global Note by attaching a copy of the applicable Final Terms
to a copy of the applicable master Temporary Global Note;
(b)
 
authenticate such Temporary Global Note;
(c)
 
deliver
 
such
 
Temporary
 
Global
 
Note
 
to
 
the
 
specified
 
common
 
depositary
 
(if
 
the
Temporary
 
Global
 
Note
 
is
 
a
 
CGN)
 
or
 
specified
 
common
 
safekeeper
 
(if
 
the
Temporary
 
Global
 
Note
 
is
 
an
 
NGN)
 
for
 
Euroclear
 
and
 
Clearstream,
 
Luxembourg
and, in the case of a Temporary Global Note which is a Eurosystem-eligible NGN, to
instruct the common safekeeper to effectuate the same;
(d)
 
ensure that
 
the
 
Notes of
 
each Tranche
 
are
 
assigned a
 
common code
 
and ISIN
 
by
Euroclear and Clearstream, Luxembourg which are different from
 
the common code
and ISIN
 
assigned to
 
Notes of
 
any other
 
Tranche
 
of the
 
same Series
 
until at
 
least
the
 
expiry
 
of
 
the
 
applicable
 
Distribution
 
Compliance
 
Period
 
of
 
such
 
Tranche
 
as
notified by the Agent to the relevant Dealer; and
(e)
 
if
 
the
 
Temporary
 
Global
 
Note
 
is
 
an
 
NGN,
 
instruct
 
Euroclear
 
and
 
Clearstream,
Luxembourg
 
to
 
make
 
the
 
appropriate
 
entries
 
in
 
their
 
records
 
to
 
reflect
 
the
 
initial
outstanding aggregate principal amount of the relevant Tranche of Notes.
3.2
 
The Agent shall only
 
be required to perform
 
its obligations under subclause
 
above if it
holds:
(a)
 
a master
 
Temporary
 
Global Note
 
duly executed by
 
a person
 
or persons
 
authorised
to
 
execute the
 
same on
 
behalf
 
of the
 
Issuer,
 
which may
 
be used
 
by the
 
Agent
 
for
the
 
purpose
 
of
 
preparing
 
a
 
Temporary
 
Global
 
Note
 
in
 
accordance
 
with
 
subclause
; and
(b)
 
a master
 
Permanent Global Note
 
duly executed
 
by a
 
person or
 
persons authorised
to
 
execute the
 
same on
 
behalf
 
of the
 
Issuer,
 
which may
 
be used
 
by the
 
Agent
 
for
the
 
purpose
 
of
 
preparing
 
a
 
Permanent
 
Global
 
Note
 
in
 
accordance
 
with
 
clause
below.
3.3
 
Where
 
the
 
Agent
 
delivers
 
any
 
authenticated
 
Global
 
Note
 
to
 
a
 
common
 
safekeeper
 
for
effectuation
 
using
 
electronic
 
means,
 
it
 
is
 
authorised
 
and
 
instructed
 
to
 
destroy
 
the
 
Global
Note
 
retained
 
by
 
it
 
following
 
its
 
receipt
 
of
 
confirmation
 
from
 
the
 
common
 
safekeeper
 
that
the relevant Global Note has been effectuated.
0010155-0003327 UKO2:
 
2004375908.9
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4.
 
DETERMINATION
 
OF
 
EXCHANGE
 
DATE
 
AND
 
ISSUE
 
OF
 
PERMANENT
 
GLOBAL
NOTES AND DEFINITIVE NOTES
4.1
 
(a)
 
The
 
Agent
 
shall
 
determine
 
the
 
Exchange
 
Date
 
for
 
each
 
Temporary
 
Global
 
Note
in
 
accordance
 
with
 
the
 
terms
 
thereof.
 
Forthwith
 
upon
 
determining
 
the
 
Exchange
Date
 
in
 
respect
 
of
 
any
 
Tranche,
 
the
 
Agent
 
shall
 
notify
 
such
 
determination
 
to
 
the
Issuer,
 
the
 
Guarantor,
 
the
 
relevant
 
Dealer,
 
Euroclear
 
and
 
Clearstream,
Luxembourg.
(b)
 
Where a Temporary Global Note is to be exchanged for a Permanent Global Note,
the Agent is hereby authorised on behalf of the Issuer:
(i)
 
in
 
the
 
case
 
of
 
the
 
first
 
Tranche
 
of
 
any
 
Series
 
of
 
Notes,
 
to
 
prepare
 
and
complete
 
a
 
Permanent
 
Global
 
Note
 
in
 
accordance
 
with
 
the
 
terms
 
of
 
the
Temporary
 
Global
 
Note
 
applicable
 
to
 
such
 
Tranche
 
by
 
attaching
 
a
 
copy
 
of
the
 
applicable
 
Final
 
Terms
 
to
 
a
 
copy
 
of
 
the
 
applicable
 
master
 
Permanent
Global Note;
(ii)
 
in the
 
case of
 
the first
 
Tranche
 
of any
 
Series of
 
Notes, to
 
authenticate such
Permanent Global Note;
(iii)
 
in
 
the
 
case
 
of
 
the
 
first
 
Tranche
 
of
 
any
 
Series
 
of
 
Notes
 
if
 
the
 
Permanent
Global
 
Note
 
is
 
a
 
CGN,
 
to
 
deliver
 
such
 
Permanent
 
Global
 
Note
 
to
 
the
common depositary
 
which
 
is holding
 
the Temporary
 
Global Note
 
applicable
to
 
such
 
Tranche
 
for
 
the
 
time
 
being
 
on
 
behalf
 
of
 
Euroclear
 
and/or
Clearstream,
 
Luxembourg
 
to
 
hold
 
on
 
behalf
 
of
 
the
 
Issuer
 
pending
 
its
exchange for such Temporary Global Note;
(iv)
 
in
 
the
 
case
 
of
 
the
 
first
 
Tranche
 
of
 
any
 
Series
 
of
 
Notes
 
if
 
the
 
Permanent
Global
 
Note
 
is
 
an
 
NGN,
 
to
 
deliver
 
the
 
Permanent
 
Global
 
Note
 
to
 
the
common
 
safekeeper
 
which
 
is
 
holding
 
the
 
Temporary
 
Global
 
Note
representing
 
the
 
Tranche
 
for
 
the
 
time
 
being
 
on
 
behalf
 
of
 
Euroclear
 
and/or
Clearstream, Luxembourg
 
to
 
effectuate (in
 
the case
 
of
 
a Permanent
 
Global
Note
 
which
 
is
 
a
 
Eurosystem-eligible
 
NGN)
 
and
 
to
 
hold
 
on
 
behalf
 
of
 
the
Issuer pending its exchange for the Temporary Global Note;
(v)
 
in the case of a subsequent Tranche of any Series of Notes if the Permanent
Global Note
 
is a
 
CGN, by
 
attaching a
 
copy of
 
the applicable
 
Final Terms
 
to
the
 
Permanent
 
Global
 
Note
 
applicable
 
to
 
the
 
relevant
 
Series
 
and
 
entering
details of any exchange in whole or part as aforesaid;
 
and
(vi)
 
in the case of a subsequent Tranche of any Series of Notes if the Permanent
Global Note is an NGN, to deliver the applicable Final Terms
 
to the specified
common
 
safekeeper
 
for
 
attachment
 
to
 
the
 
Permanent
 
Global
 
Note
applicable to the relevant Series.
5.
 
ISSUE OF DEFINITIVE
 
NOTES
5.1
 
Where a Global Note is to be exchanged for Definitive
 
Notes in accordance with its terms,
the Agent is hereby authorised on behalf of the Issuer:
(a)
 
to authenticate such Definitive Note(s) in accordance with
 
the provisions of this
Agreement; and
(b)
 
to
 
deliver
 
such
 
Definitive
 
Note(s)
 
to
 
or
 
to
 
the
 
order
 
of
 
Euroclear
 
and/or
Clearstream, Luxembourg.
0010155-0003327 UKO2:
 
2004375908.9
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The
 
Agent
 
shall
 
notify
 
the
 
Issuer
 
forthwith
 
upon
 
receipt
 
of
 
a
 
request
 
for
 
issue
 
of
 
(a)
Definitive
 
Note(s)
 
in
 
accordance
 
with
 
the
 
provisions
 
of
 
a
 
Temporary
 
Global
 
Note
 
or
Permanent Global
 
Note, as
 
the case
 
may be,
 
(and the
 
aggregate nominal
 
amount of
 
such
Temporary
 
Global Note
 
or Permanent
 
Global Note,
 
as the
 
case may
 
be, to
 
be exchanged
in connection therewith).
5.2
 
The
 
Issuer
 
undertakes
 
to
 
deliver
 
to
 
the
 
Agent
 
sufficient
 
numbers
 
of
 
executed
 
Definitive
Notes with,
 
if applicable, Coupons and Talons
 
attached to enable the
 
Agent to comply with
its obligations under this clause.
6.
 
TERMS OF ISSUE
6.1
 
The Agent shall cause all
 
Temporary
 
Global Notes, Permanent Global Notes and
 
Definitive
Notes
 
delivered
 
to
 
and
 
held
 
by
 
it
 
under
 
this
 
Agreement
 
to
 
be
 
maintained
 
in
 
safe
 
custody
and shall
 
ensure that
 
such Notes
 
are issued
 
only in
 
accordance with
 
the provisions
 
of this
Agreement and the relevant Global Note and Conditions.
6.2
 
Subject
 
to
 
the
 
procedures
 
set
 
out
 
in
 
the
 
Procedures
 
Memorandum,
 
for
 
the
 
purposes
 
of
subclause
 
the Agent
 
is entitled
 
to treat
 
a telephone
 
or facsimile
 
communication from
 
a
person who
 
the Agent
 
believes to
 
be the
 
authorised representative of
 
the Issuer
 
or,
 
as the
case
 
may
 
be,
 
the
 
Guarantor,
 
named
 
in
 
the
 
list
 
referred
 
to
 
in,
 
or
 
notified
 
pursuant
 
to,
subclause
 
as sufficient
 
instructions and
 
authority of
 
the
 
Issuer and
 
the
 
Guarantor for
the Agent to act in accordance with subclause
6.3
 
In the
 
event that
 
a person
 
who has
 
signed on
 
behalf of
 
the Issuer
 
any Note
 
not yet
 
issued
but
 
held
 
by
 
the
 
Agent
 
in
 
accordance
 
with
 
subclause
 
ceases
 
to
 
be
 
authorised
 
as
described in
 
subclause
, the
 
Agent shall
 
(unless the
 
Issuer gives
 
written notice
 
to the
Agent that Notes signed by that person do not constitute valid and binding
 
obligations of the
Issuer or
 
otherwise until
 
replacements have
 
been provided
 
to the
 
Agent) continue
 
to have
authority to
 
issue any
 
such Notes,
 
and
 
the Issuer
 
hereby warrants
 
to the
 
Agent that
 
such
Notes
 
shall,
 
unless
 
notified
 
as
 
aforesaid,
 
be
 
valid
 
and
 
binding
 
obligations
 
of
 
the
 
Issuer.
Promptly
 
upon
 
such
 
person
 
ceasing
 
to
 
be
 
authorised,
 
the
 
Issuer
 
shall
 
provide
 
the
 
Agent
with replacement Notes and upon receipt of such replacement Notes the Agent shall cancel
and destroy
 
the Notes
 
held by
 
it which
 
are signed by
 
such person and
 
shall provide to
 
the
Issuer
 
a
 
confirmation
 
of
 
destruction
 
in
 
respect
 
thereof
 
specifying
 
the
 
Notes
 
so
 
cancelled
and destroyed.
6.4
 
If the
 
Agent pays an
 
amount (the
Advance
) to
 
the Issuer
 
on the
 
basis that
 
a payment (the
Payment
) has
 
been, or
 
will be,
 
received from
 
a Dealer
 
and if
 
the Payment
 
is not
 
received
by the Agent on the date
 
the Agent pays the Issuer,
 
the Issuer, failing which
 
the Guarantor,
shall
 
repay
 
to
 
the
 
Agent
 
the
 
Advance
 
and
 
shall
 
pay
 
interest
 
on
 
the
 
Advance
 
(or
 
the
unreimbursed portion
 
thereof) from
 
(and including)
 
the date
 
such Advance
 
is made
 
to (but
excluding) the earlier of repayment of the Advance and receipt by the Agent of the Payment
(at a rate quoted
 
at that time by
 
the Agent as the aggregate
 
of one per cent.
 
and its cost of
funding the Advance
 
provided that evidence of
 
the basis of
 
such rate
 
is given to the
 
Issuer
if so required).
6.5
 
Except in the
 
case of issues
 
where the Agent
 
does not act
 
as receiving bank for
 
the Issuer
in respect
 
of the
 
purchase price
 
of the
 
Notes being
 
issued, if
 
on the
 
relevant Issue
 
Date a
Dealer
 
does
 
not
 
pay
 
the
 
full
 
purchase
 
price
 
due
 
from
 
it
 
in
 
respect
 
of
 
any
 
Note
 
(the
Defaulted
 
Note
)
 
and,
 
as
 
a
 
result,
 
the
 
Defaulted
 
Note
 
remains
 
in
 
the
 
Agent's
 
distribution
account with
 
Euroclear and/or
 
Clearstream, Luxembourg
 
after such
 
Issue Date,
 
the Agent
will continue
 
to
 
hold
 
the
 
Defaulted
 
Note to
 
the
 
order
 
of
 
the
 
Issuer.
 
The Agent
 
shall notify
the Issuer
 
forthwith of
 
the failure
 
of the
 
Dealer to
 
pay the
 
full purchase
 
price due
 
from it
 
in
respect
 
of
 
any
 
Defaulted
 
Note
 
and,
 
subsequently,
 
shall
 
notify
 
the
 
Issuer
 
forthwith
 
upon
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receipt from the Dealer of the full purchase price in respect of such Defaulted
 
Note.
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7.
 
PAYMENTS
7.1
 
The
 
Issuer,
 
failing
 
which
 
the
 
Guarantor
 
will,
 
before
 
10.00
 
a.m.
 
(local
 
time
 
in
 
the
 
relevant
financial
 
centre
 
of
 
the
 
payment),
 
on
 
each
 
date
 
on
 
which
 
any
 
payment
 
in
 
respect
 
of
 
any
Note
 
becomes
 
due,
 
transfer
 
to
 
an
 
account
 
specified
 
by
 
the
 
Agent
 
such
 
amount
 
in
 
the
relevant
 
currency as
 
shall be
 
sufficient
 
for
 
the
 
purposes of
 
such
 
payment in
 
funds
 
settled
through
 
such
 
payment
 
system
 
as
 
the
 
Agent
 
and
 
the
 
Issuer
 
or,
 
as
 
the
 
case
 
may
 
be,
 
the
Guarantor may agree.
7.2
 
The
 
Issuer,
 
failing
 
which
 
the
 
Guarantor
 
will
 
ensure
 
that
 
no
 
later
 
than
 
10.00
 
a.m.
 
(London
time)
 
on
 
the
 
Business
 
Day
 
(as
 
defined
 
below)
 
immediately
 
preceding
 
the
 
date
 
on
 
which
any payment is to
 
be made to the
 
Agent pursuant to subclause
, the Agent shall
 
receive
a payment confirmation from the paying bank of the Issuer.
For the purposes of this
 
clause
Business Day
means a day which is both:
(a)
 
a
 
day
 
on
 
which
 
commercial banks
 
and
 
foreign
 
exchange
 
markets
 
settle
 
payments
and
 
are
 
open
 
for
 
general
 
business
 
(including
 
dealing
 
in
 
foreign
 
exchange
 
and
foreign currency deposits) in London and any
 
other place specified in the applicable
Final Terms
 
as an Additional Business Centre; and
(b)
 
either
 
(i)
 
in
 
relation
 
to
 
a
 
payment
 
to
 
be
 
made
 
in
 
a
 
Specified
 
Currency
 
other
 
than
euro,
 
a
 
day
 
on
 
which
 
commercial
 
banks
 
and
 
foreign
 
exchange
 
markets
 
settle
payments
 
in
 
the
 
principal
 
financial
 
centre
 
of
 
the
 
country
 
of
 
the
 
relevant
 
Specified
Currency
 
(if
 
other
 
than
 
London
 
and
 
any
 
Additional
 
Business
 
Centre)
 
and
 
which,
 
if
the Specified
 
Currency is
 
New Zealand
 
Dollars, shall
 
be Auckland
 
or (ii)
 
in relation
to
 
any
 
sum
 
payable in
 
euro,
 
a
 
day
 
on
 
which the
 
Trans-European
 
Automated
 
Real
Time Gross Settlement Express Transfer (TARGET 2) System is operating.
7.3
 
The
 
Agent
 
shall
 
ensure
 
that
 
payments
 
of
 
both
 
principal
 
and
 
interest
 
in
 
respect
 
of
 
a
Temporary
 
Global
 
Note
 
will
 
be
 
made
 
only
 
to
 
the
 
extent
 
that
 
certification
 
of
 
non-U.S.
beneficial ownership as required by
 
U.S. securities laws and U.S.
 
Treasury regulations has
been
 
received
 
from
 
Euroclear
 
and/or
 
Clearstream,
 
Luxembourg
 
in
 
accordance
 
with
 
the
terms thereof.
7.4
 
Subject to
 
the
 
receipt by
 
the
 
Agent of
 
the
 
payment confirmation
 
as provided
 
in
 
subclause
 
above, the Agent or the relevant Paying Agent shall pay or cause
 
to be paid all amounts
due
 
in
 
respect
 
of
 
the
 
Notes
 
on
 
behalf
 
of
 
the
 
Issuer
 
(failing
 
which
 
the
 
Guarantor)
 
in
 
the
manner
 
provided in
 
the Conditions.
 
If
 
any
 
payment provided
 
for
 
in
 
subclause
 
is made
late but otherwise in accordance with
 
the provisions of this Agreement, the Agent
 
and each
Paying
 
Agent
 
shall
 
nevertheless
 
make
 
payments
 
in
 
respect
 
of
 
the
 
Notes
 
as
 
aforesaid
following receipt by it of such payment.
7.5
 
If
 
for
 
any
 
reason
 
the
 
Agent
 
considers
 
in
 
its
 
reasonable
 
opinion
 
that
 
the
 
amounts
 
to
 
be
received by
 
the Agent
 
pursuant to
 
subclause
 
will be,
 
or the
 
amounts actually
 
received
by
 
it
 
pursuant
 
thereto
 
are,
 
insufficient
 
to
 
satisfy
 
all
 
claims
 
in
 
respect
 
of
 
all
 
payments
 
then
falling due in respect
 
of the Notes, neither the
 
Agent nor any Paying Agent shall
 
be obliged
to pay any such claims until the Agent has received the full amount
 
of all such payments.
7.6
 
Without prejudice to
 
subclauses
 
and
 
if the
 
Agent pays any
 
amounts to the
 
holders
of Notes
 
or Coupons or to
 
any Paying Agent at a
 
time when it has
 
not received payment in
full
 
in
 
respect
 
of
 
the
 
relevant
 
Notes
 
in
 
accordance
 
with
 
subclause
 
(the
 
excess
 
of
 
the
amounts
 
so
 
paid
 
over
 
the
 
amounts
 
so
 
received
 
being
 
the
Shortfall
),
 
the
 
Issuer,
 
failing
which the Guarantor will, in addition to paying amounts due under subclause
 
pay to the
Agent on
 
demand interest
 
(at
 
a rate
 
which represents
 
the
 
aggregate of
 
one per
 
cent. and
the
 
Agent's
 
cost
 
of
 
funding
 
the
 
Shortfall)
 
on
 
the
 
Shortfall
 
(or
 
the
 
unreimbursed
 
portion
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thereof) until the receipt in full by the Agent of the Shortfall.
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7.7
 
The Agent shall on demand promptly reimburse each Paying Agent for payments in respect
of Notes
 
properly made
 
by such
 
Paying Agent
 
in accordance
 
with this
 
Agreement and
 
the
Conditions unless the Agent has notified the Paying Agent,
 
prior to the opening of business
in
 
the
 
location
 
of
 
the
 
office
 
of
 
the
 
Paying
 
Agent
 
through
 
which
 
payment
 
in
 
respect
 
of
 
the
Notes can
 
be made
 
on the
 
due date
 
of a
 
payment in
 
respect of
 
the Notes,
 
that the
 
Agent
does
 
not
 
expect to
 
receive sufficient
 
funds
 
to
 
make
 
payment
 
of
 
all
 
amounts
 
falling due
 
in
respect of such Notes.
7.8
 
Whilst
 
any
 
Notes
 
are
 
represented
 
by
 
Global
 
Notes,
 
all
 
payments
 
due
 
in
 
respect
 
of
 
such
Notes shall
 
be made to, or to the order of, the
 
holder of the Global Notes, subject to and in
accordance with the
 
provisions of the
 
Global Notes.
 
On the occasion
 
of any such
 
payment
(i) in the
 
case of a
 
CGN, the Paying
 
Agent to which
 
the Global Note
 
was presented for
 
the
purpose
 
of
 
making
 
such
 
payment
 
shall
 
cause
 
the
 
appropriate
 
Schedule
 
to
 
the
 
relevant
Global Note to be annotated so as to
 
evidence the amounts and dates of such payments of
principal
 
and/or
 
interest
 
as
 
applicable
 
or
 
(ii)
 
in
 
the
 
case
 
of
 
any
 
Global
 
Note
 
which
 
is
 
an
NGN, the Agent shall instruct Euroclear and Clearstream, Luxembourg to make appropriate
entries in their records to reflect such payment.
7.9
 
If the
 
amount of principal
 
and/or interest then
 
due for
 
payment is not
 
paid in full
 
(otherwise
than
 
by
 
reason
 
of
 
a
 
deduction
 
required
 
by
 
law
 
to
 
be
 
made
 
therefrom
 
or
 
by
 
reason
 
of
 
a
FATCA
 
Withholding),
(i) the Paying
 
Agent to which
 
a Note
 
is presented for
 
the purpose of
 
making such payment
shall,
 
unless
 
the
 
Note
 
is
 
an
 
NGN,
 
make
 
a
 
record
 
of
 
such
 
Shortfall
 
on
 
the
 
Note
 
and
 
such
record shall,
 
in the
 
absence of manifest
 
error,
 
be
prima facie
evidence that the
 
payment in
question has not to that extent been
 
made or (ii) in the case
 
of any Global Note which is an
NGN, the Agent shall instruct Euroclear and Clearstream, Luxembourg to make appropriate
entries in their records to reflect such shortfall in payment.
7.10
 
In
 
the
 
event that
 
(a) the
 
Issuer
 
is or
 
becomes a
 
Participating FFI,
 
(b)
 
Notes are
 
issued or
amended (or any
 
terms of the
 
Notes are waived)
 
after the Grandfathering
 
Date and (c)
 
the
Issuer
 
or
 
the
 
Guarantor
 
determines
 
in
 
its
 
sole
 
discretion
 
that
 
FATCA
 
Withholding
 
will
 
be
required in connection with
 
any payment due to the
 
Agent on any Notes, then
 
the Issuer or
the Guarantor will be
 
entitled to re-direct or reorganise any
 
such payment in any way
 
that it
sees fit
 
in order
 
that the
 
payment may
 
be made
 
without FATCA
 
Withholding provided
 
that
any
 
such
 
redirected
 
or
 
reorganised
 
payment
 
is
 
otherwise
 
made
 
in
 
accordance
 
with
 
this
Agreement.
 
The
 
Issuer
 
will
 
promptly
 
notify
 
the
 
Agent
 
and
 
the
 
Noteholders
 
of
 
any
 
such
redirection or reorganisation.
7.11
 
The Agent
 
shall be
 
entitled to
 
deduct FATCA
 
Withholding, and
 
shall have
 
no obligation
 
to
gross-up
 
any
 
payment
 
hereunder
 
or
 
to
 
pay
 
any
 
additional
 
amount
 
as
 
a
 
result
 
of
 
such
FATCA
 
Withholding.
8.
 
DETERMINATIONS
 
AND
 
NOTIFICATIONS
 
IN
 
RESPECT
 
OF
 
NOTES
 
AND
 
INTEREST
DETERMINATION
8.1
Determinations and Notifications
(a)
 
The Agent shall make
 
all such determinations and calculations (howsoever
 
described) as it
is required to do under the Conditions, all subject to and in accordance
 
with the Conditions.
(b)
 
The Agent
 
shall not
 
be responsible
 
to
 
the Issuer,
 
the Guarantor
 
or to
 
any third
 
party as
 
a
result
 
of
 
the
 
Agent
 
having
 
acted
 
on
 
any
 
quotation
 
given
 
by
 
any
 
Reference
 
Bank
 
which
subsequently may be found to be incorrect.
(c)
 
The
 
Agent
 
shall
 
promptly
 
notify
 
(and
 
confirm
 
in
 
writing
 
to)
 
the
 
Issuer,
 
the
 
Guarantor,
 
the
other Paying
 
Agents and
 
(in respect
 
of a
 
Series of
 
Notes listed
 
on a
 
Stock Exchange)
 
the
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relevant Stock
 
Exchange of,
inter alia
, each
 
Rate of
 
Interest, Interest
 
Amount and
 
Interest
Payment
 
Date
 
and
 
all
 
other
 
amounts, rates
 
and
 
dates
 
which
 
it
 
is
 
obliged
 
to
 
determine
 
or
calculate under the Conditions as
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soon
 
as
 
practicable
 
after
 
the
 
determination
 
thereof
 
and
 
of
 
any
 
subsequent
 
amendment
thereto pursuant to the Conditions.
(d)
 
The
 
Agent
 
shall
 
use
 
its
 
best
 
endeavours to
 
cause
 
each
 
Rate
 
of
 
Interest,
 
Interest
 
Amount
and
 
Interest
 
Payment
 
Date
 
and
 
all
 
other
 
amounts,
 
rates
 
and
 
dates
 
which
 
it
 
is
 
obliged
 
to
determine or calculate under the Conditions to be
 
published as required in accordance with
the Conditions as soon as possible after their determination or
 
calculation.
(e)
 
If the Agent does
 
not at any material time
 
for any reason determine
 
and/or calculate and/or
publish the Rate of Interest, Interest Amount and/or Interest Payment
 
Date in respect of any
Interest
 
Period
 
or
 
any
 
other
 
amount,
 
rate
 
or
 
date
 
as
 
provided
 
in
 
this
 
clause,
 
it
 
shall
forthwith notify the Issuer, the Guarantor and the other Paying Agents of such fact.
(f)
 
Determinations
 
with
 
regard
 
to
 
Notes
 
shall
 
be
 
made
 
by
 
the
 
Calculation Agent
 
specified
 
in
the
 
applicable Final
 
Terms
 
in
 
the
 
manner
 
specified
 
in
 
the
 
applicable Final
 
Terms.
 
Unless
otherwise
 
agreed
 
between
 
the
 
Issuer
 
and
 
the
 
relevant
 
Dealer
 
or
 
unless
 
the
 
Agent
 
is
 
the
Calculation
 
Agent
 
(in
 
which
 
case
 
the
 
provisions
 
of
 
this
 
Agreement
 
shall
 
apply),
 
such
determinations shall be made on the basis of a Calculation Agency Agreement substantially
in the form of Appendix 1 to this Agreement.
8.2
Interest Determination,
 
Screen Rate Determination
 
including Fallback
 
Provisions
(a)
 
Where Screen Rate Determination is specified in the
 
applicable Final Terms
 
as the manner
in
 
which
 
the
 
Rate
 
of
 
Interest
 
is
 
to
 
be
 
determined,
 
the
 
Rate
 
of
 
Interest
 
for
 
each
 
Interest
Period will be determined in accordance with the Conditions.
(b)
 
The Conditions also contain provisions for determining the Rate of Interest
 
in the event that
the
 
Relevant
 
Screen
 
Page
 
is
 
not
 
available
 
or
 
the
 
quotation
 
or
 
quotations
 
required
 
by
 
the
Conditions are unavailable or following a Benchmark Event or Benchmark
 
Transition Event.
9.
 
NOTICE OF ANY WITHHOLDING
 
OR DEDUCTION
In the
 
event that
 
(a) the
 
Issuer or
 
the Guarantor
 
is or
 
becomes a
 
Participating FFI
 
and (b)
Notes
 
are
 
issued
 
or
 
amended
 
(or
 
any
 
terms
 
of
 
the
 
Notes
 
are
 
waived)
 
after
 
the
Grandfathering Date, the Issuer will notify the Agent as soon as
 
is practicable of: (i) the fact
that
 
the
 
Issuer
 
or
 
the
 
Guarantor
 
is
 
or
 
has
 
become
 
a
 
Participating
 
FFI,
 
and
 
(ii)
 
any
 
other
information
 
known
 
to
 
the
 
Issuer
 
and
 
pertaining
 
to
 
the
 
Issuer
 
or,
 
as
 
the
 
case
 
may
 
be,
 
the
Guarantor,
 
necessary
 
for
 
the
 
Agent
 
to
 
determine
 
the
 
amount,
 
if
 
any,
 
it
 
is
 
required
 
to
withhold or
 
deduct in
 
respect of
 
any FATCA
 
Withholding in
 
relation to
 
any payment
 
under
the Notes.
10.
 
DUTIES OF THE
 
AGENT IN CONNECTION
 
WITH EARLY REDEMPTION
10.1
 
If
 
the
 
Issuer
 
decides
 
to
 
redeem
 
any
 
Notes
 
for
 
the
 
time
 
being
 
outstanding
 
prior
 
to
 
their
Maturity Date in accordance with
 
the Conditions, the Issuer shall,
 
unless otherwise agreed,
give notice of such decision to the Agent not less than
 
15 days before the date on which the
Issuer
 
will
 
give
 
notice
 
to
 
the
 
Noteholders
 
in
 
accordance
 
with
 
the
 
Conditions
 
of
 
such
redemption
 
in
 
order
 
to
 
enable
 
the
 
Agent
 
to
 
undertake
 
its
 
obligations
 
herein
 
and
 
in
 
the
Conditions.
10.2
 
If
 
some
 
only
 
of
 
the
 
Notes
 
are
 
to
 
be
 
redeemed
 
on
 
such
 
date,
 
the
 
Agent
 
shall
 
make
 
the
required
 
drawing
 
in
 
accordance
 
with
 
the
 
Conditions
 
but
 
shall
 
give
 
the
 
Issuer
 
and
 
the
Guarantor
 
reasonable
 
notice
 
of
 
the
 
time
 
and
 
place
 
proposed
 
for
 
such
 
drawing
 
and
 
the
Issuer shall be entitled to send representatives to attend such drawing.
10.3
 
The
 
Agent
 
shall
 
publish
 
the
 
notice
 
required
 
in
 
connection
 
with
 
any
 
such
 
redemption
 
and
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shall
 
at
 
the
 
same
 
time
 
also
 
publish
 
a
 
separate
 
list
 
of
 
the
 
serial
 
numbers
 
of
 
any
 
Notes
previously drawn and not
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presented
 
for
 
redemption.
 
Such
 
notice
 
shall
 
specify
 
the
 
date
 
fixed
 
for
 
redemption,
 
the
redemption amount,
 
the manner
 
in which
 
redemption will
 
be effected
 
and, in
 
the case
 
of a
partial
 
redemption,
 
the
 
serial
 
numbers
 
of
 
the
 
Notes
 
to
 
be
 
redeemed.
 
Such
 
notice
 
will
 
be
published
 
in
 
accordance
 
with
 
the
 
Conditions.
 
The
 
Agent
 
will
 
also
 
notify
 
the
 
other
 
Paying
Agents of any date fixed for redemption of any Notes.
10.4
 
Each Paying Agent will keep a stock of Put Notices and will make such notices available on
demand to holders of Notes, the Conditions of which provide for redemption at the option of
Noteholders.
 
Upon
 
receipt
 
of
 
any
 
Note
 
deposited
 
in
 
the
 
exercise
 
of
 
such
 
option
 
in
accordance with
 
the Conditions,
 
the Paying
 
Agent with
 
which such
 
Note is
 
deposited shall
hold
 
such
 
Note (together
 
with
 
any Coupons
 
and Talons
 
relating to
 
it
 
deposited with
 
it)
 
on
behalf of
 
the depositing
 
Noteholder (but
 
shall not,
 
save as
 
provided below,
 
release it)
 
until
the
 
due
 
date
 
for
 
redemption
 
of
 
the
 
relevant
 
Note
 
consequent
 
upon
 
the
 
exercise
 
of
 
such
option, when, subject as provided below, it shall present such Note (and
 
any such Coupons
and Talons)
 
to itself
 
for payment
 
of the
 
amount due
 
thereon together with
 
any interest
 
due
on such
 
date in accordance
 
with the
 
Conditions and shall
 
pay such moneys
 
in accordance
with the
 
directions of
 
the Noteholder
 
contained in
 
the relevant
 
Put Notice.
 
If, prior
 
to such
due
 
date
 
for
 
its
 
redemption, such
 
Note
 
becomes
 
immediately
 
due
 
and
 
payable or
 
if
 
upon
due
 
presentation
 
payment
 
of
 
such
 
redemption
 
moneys
 
is
 
improperly
 
withheld
 
or
 
refused,
the
 
Paying
 
Agent
 
concerned
 
shall
 
post
 
such
 
Note
 
(together
 
with
 
any
 
such
 
Coupons
 
and
Talons)
 
by
 
uninsured
 
post
 
to,
 
and
 
at
 
the
 
risk
 
of,
 
the
 
relevant
 
Noteholder
 
unless
 
the
Noteholder
 
has
 
otherwise requested
 
and
 
paid the
 
costs
 
of
 
such
 
insurance to
 
the
 
relevant
Paying Agent at
 
the time of
 
depositing the Notes at
 
such address as
 
may have been
 
given
by the
 
Noteholder in the
 
relevant Put
 
Notice.
 
At the
 
end of
 
each period for
 
the exercise of
such option,
 
each Paying
 
Agent shall
 
promptly notify
 
the
 
Agent of
 
the
 
principal amount
 
of
the
 
Notes
 
in
 
respect
 
of
 
which
 
such
 
option
 
has
 
been
 
exercised
 
with
 
it
 
together
 
with
 
their
serial numbers and the Agent shall promptly notify such details to the Issuer.
 
The Issuer
 
or
the
 
Guarantor
 
shall
 
provide
 
to
 
the
 
Agent
 
sufficient
 
supplies
 
of
 
blank
 
Put
 
Notices
 
for
 
such
purposes.
11.
 
RECEIPT AND PUBLICATION OF NOTICES
11.1
 
Forthwith
 
upon
 
the
 
receipt
 
by
 
the
 
Agent
 
of
 
a
 
demand
 
or
 
notice
 
from
 
any
 
Noteholder
 
in
accordance with the Conditions the Agent shall forward a copy thereof to the Issuer and the
Guarantor.
11.2
 
On behalf of and at the request and expense of the Issuer (failing which the Guarantor), the
Agent
 
shall
 
cause
 
to
 
be
 
published
 
all
 
notices
 
required
 
to
 
be
 
given
 
by
 
the
 
Issuer
 
or
 
the
Guarantor to the Noteholders in accordance with the Conditions.
12.
 
CANCELLATION OF NOTES, COUPONS
 
AND TALONS
12.1
 
All
 
Notes
 
which
 
are
 
redeemed,
 
all
 
Coupons
 
which
 
are
 
paid
 
and
 
all
 
Talons
 
which
 
are
exchanged shall
 
be cancelled
 
by the
 
Agent or
 
Paying Agent
 
by which
 
they are
 
redeemed,
paid
 
or
 
exchanged.
 
In
 
addition,
 
the
 
Issuer
 
and
 
the
 
Guarantor
 
shall
 
immediately notify
 
the
Agent
 
in
 
writing
 
of
 
all
 
Notes
 
which
 
are
 
purchased
 
by
 
or
 
on
 
behalf
 
of
 
the
 
Issuer
 
or
 
the
Guarantor and
 
all such
 
Notes surrendered
 
to a
 
Paying Agent
 
for cancellation,
 
together (in
the case of Definitive Notes) with all unmatured Coupons or Talons (if any) attached thereto
or
 
surrendered
 
therewith,
 
shall
 
be
 
cancelled
 
by
 
the
 
Paying
 
Agent
 
to
 
which
 
they
 
are
surrendered.
 
Each
 
of
 
the
 
other
 
Paying
 
Agents
 
shall
 
give
 
to
 
the
 
Agent
 
details
 
of
 
all
payments
 
made
 
by
 
it
 
and
 
shall
 
deliver
 
all
 
cancelled
 
Notes,
 
Coupons
 
and
 
Talons
 
to
 
the
Agent.
12.2
 
A certificate stating:
(a)
 
the
 
aggregate
 
nominal
 
amount
 
of
 
Notes
 
which
 
have
 
been
 
redeemed
 
and
 
the
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aggregate amount paid in respect thereof;
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(b)
 
the number of Notes cancelled together (in the case of Notes in definitive
 
form) with
details of all unmatured Coupons or Talons (if any) attached thereto or delivered
therewith;
(c)
 
the aggregate amount paid
 
in respect of interest on
 
the Notes;
(d)
 
the total number by
 
maturity date of Coupons and
 
Talons
 
so cancelled; and
(e)
 
(in the case of Definitive
 
Notes) the serial numbers of
 
such Notes,
shall
 
be
 
given
 
to
 
the
 
Issuer
 
by
 
the
 
Agent
 
as
 
soon
 
as
 
reasonably
 
practicable
 
and
 
in
 
any
event upon written
 
request within three
 
months after the
 
date of such
 
repayment or,
 
as the
case may be, payment or exchange.
12.3
 
The
 
Agent
 
shall
 
destroy
 
all
 
cancelled
 
Notes,
 
Coupons
 
and
 
Talons
 
and,
 
forthwith
 
upon
destruction, furnish
 
the Issuer
 
upon written
 
request with
 
a certificate
 
of the
 
serial numbers
of
 
the
 
Notes
 
(in
 
the
 
case
 
of
 
Notes
 
in
 
definitive
 
form)
 
and
 
the
 
number
 
by
 
maturity
 
date
 
of
Coupons and Talons so destroyed.
12.4
 
Without
 
prejudice
 
to
 
the
 
obligations
 
of
 
the
 
Agent
 
pursuant
 
to
 
subclause
 
the
 
Agent
shall keep
 
a full
 
and complete
 
record of
 
all
 
Notes, Coupons
 
and Talons
 
(other than
 
serial
numbers of Coupons) and of their redemption, purchase by or on behalf of the Issuer or the
Guarantor
 
and
 
cancellation,
 
payment
 
or
 
exchange
 
(as
 
the
 
case
 
may
 
be)
 
and
 
of
 
all
replacement
 
Notes,
 
Coupons
 
or
 
Talons
 
issued
 
in
 
substitution
 
for
 
mutilated,
 
defaced,
destroyed,
 
lost
 
or
 
stolen
 
Notes,
 
Coupons
 
or
 
Talons.
 
The
 
Agent
 
shall
 
in
 
respect
 
of
 
the
Coupons of each maturity retain (in
 
the case of Coupons other than
 
Talons)
 
until the expiry
of ten years from the Relevant Date in respect of such Coupons and (in the
 
case of Talons)
indefinitely
 
either
 
all
 
paid
 
or
 
exchanged
 
Coupons
 
of
 
that
 
maturity
 
or
 
a
 
list
 
of
 
the
 
serial
numbers
 
of
 
Coupons
 
of
 
that
 
maturity
 
still
 
remaining
 
unpaid
 
or
 
unexchanged.
 
The
 
Agent
shall at
 
all reasonable
 
times make
 
such record
 
available to
 
the
 
Issuer,
 
the Guarantor
 
and
any persons
 
authorised by
 
it for
 
inspection and
 
for the
 
taking of
 
copies thereof
 
or extracts
therefrom.
12.5
 
The
 
Agent
 
is
 
authorised
 
by
 
the
 
Issuer
 
and
 
instructed
 
(a)
 
in
 
the
 
case
 
of
 
any
 
Global
 
Note
which is
 
a CGN,
 
to endorse
 
or to
 
arrange for
 
the endorsement
 
of the
 
relevant Global
 
Note
to reflect the reduction in the nominal amount represented by it by the amount so redeemed
or
 
purchased
 
and
 
cancelled
 
and
 
(b)
 
in
 
the
 
case
 
of
 
any
 
Global
 
Note
 
which
 
is
 
an
 
NGN,
 
to
instruct
 
Euroclear
 
and
 
Clearstream,
 
Luxembourg
 
to
 
make
 
appropriate
 
entries
 
in
 
their
records
 
to
 
reflect
 
such
 
redemption
 
or
 
purchase
 
and
 
cancellation,
 
as
 
the
 
case
 
may
 
be;
provided, that, in the case of a purchase or cancellation, the Issuer has
 
notified the Agent of
the same in accordance with subclause 12.1.
12.6
 
All records and certificates made or given
 
pursuant to this clause and clause
 
shall make
a distinction between Notes, Coupons and Talons of each Series.
13.
 
ISSUE OF REPLACEMENT
 
NOTES, COUPONS
 
AND TALONS
13.1
 
The Issuer will cause a sufficient quantity of additional forms of Notes, Coupons and Talons
to be
 
available, upon request,
 
to the
 
Agent at
 
its specified
 
office for
 
the purpose
 
of issuing
replacement Notes, Coupons and Talons as provided below.
13.2
 
The
 
Agent
 
will,
 
subject
 
to
 
and
 
in
 
accordance
 
with
 
the
 
Conditions
 
and
 
the
 
following
provisions
 
of
 
this
 
clause,
 
cause
 
to
 
be
 
delivered
 
any
 
replacement
 
Notes,
 
Coupons
 
and
Talons
 
which
 
the
 
Issuer
 
may
 
determine
 
to
 
issue
 
in
 
place
 
of
 
Notes,
 
Coupons
 
and
 
Talons
which have been lost, stolen, mutilated, defaced or destroyed.
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13.3
 
In
 
the
 
case of
 
a mutilated
 
or
 
defaced Note,
 
the
 
Agent
 
shall ensure
 
that (unless
 
otherwise
covered
 
by
 
such
 
indemnity
 
as
 
the
 
Issuer
 
may
 
reasonably
 
require)
 
any
 
replacement
 
Note
will only have attached
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to it Coupons and Talons corresponding to those (if any) attached to the mutilated or
defaced Note which is presented for replacement.
13.4
 
The
 
Agent
 
shall
 
not
 
issue
 
any
 
replacement
 
Note,
 
Coupon
 
or
 
Talon
 
unless
 
and
 
until
 
the
claimant therefor shall have:
(a)
 
paid such costs and
 
expenses as may be incurred
 
in connection therewith;
(b)
 
furnished it with such
 
evidence and indemnity
 
as the Issuer may
 
reasonably require;
and
(c)
 
in the case of any mutilated
 
or defaced Note, Coupon or
 
Talon, surrendered it to the
Agent.
13.5
 
The Agent
 
shall cancel any
 
mutilated or
 
defaced Notes, Coupons
 
and Talons
 
in respect
 
of
which replacement
 
Notes, Coupons
 
and Talons
 
have been
 
issued pursuant
 
to this
 
clause
and
 
shall
 
furnish
 
the
 
Issuer
 
with
 
a
 
certificate
 
stating
 
the
 
serial
 
numbers
 
of
 
the
 
Notes,
Coupons and Talons
 
so cancelled and, unless otherwise
 
instructed by the Issuer in
 
writing,
shall
 
destroy
 
such
 
cancelled
 
Notes,
 
Coupons
 
and
 
Talons
 
and
 
furnish
 
the
 
Issuer
 
with
 
a
destruction certificate containing the information specified
 
in subclause
13.6
 
The
 
Agent
 
shall,
 
on
 
issuing any
 
replacement Note,
 
Coupon
 
or
 
Talon,
 
forthwith
 
inform the
Issuer and the other Paying Agents of the serial number of such replacement Note, Coupon
or Talon
 
issued and
 
(if known)
 
of the
 
serial number
 
of the
 
Note, Coupon
 
or Talon
 
in place
of
 
which
 
such
 
replacement
 
Note,
 
Coupon
 
or
 
Talon
 
has
 
been
 
issued.
 
Whenever
replacement
 
Coupons
 
or
 
Talons
 
are
 
issued
 
pursuant
 
to
 
the
 
provisions of
 
this
 
clause,
 
the
Agent
 
shall
 
also
 
notify
 
the
 
other
 
Paying
 
Agents
 
of
 
the
 
maturity
 
dates
 
of
 
the
 
lost,
 
stolen,
mutilated,
 
defaced
 
or
 
destroyed
 
Coupons
 
or
 
Talons
 
and
 
of
 
the
 
replacement
 
Coupons
 
or
Talons
 
issued.
13.7
 
The
 
Agent
 
shall
 
keep
 
a
 
full
 
and
 
complete
 
record
 
of
 
all
 
replacement
 
Notes,
 
Coupons
 
and
Talons
 
issued and
 
shall make
 
such record
 
available at
 
all reasonable
 
times to
 
the Issuer,
the Guarantor
 
and any
 
persons authorised
 
by it
 
for inspection
 
and for
 
the taking
 
of copies
thereof or extracts therefrom.
13.8
 
Whenever any Note, Coupon
 
or Talon
 
for which a
 
replacement Note, Coupon or
 
Talon
 
has
been issued
 
and in
 
respect of
 
which the
 
serial number
 
is known
 
is presented
 
to the
 
Agent
or
 
any
 
of
 
the
 
other
 
Paying
 
Agents
 
for
 
payment,
 
the
 
Agent
 
or,
 
as
 
the
 
case
 
may
 
be,
 
the
relevant
 
other
 
Paying
 
Agent
 
shall
 
immediately
 
send
 
notice
 
thereof
 
to
 
the
 
Issuer
 
and
 
the
other Paying Agents.
14.
 
COPIES OF DOCUMENTS
 
AVAILABLE
 
FOR INSPECTION OR
 
COLLECTION
14.1
 
The
 
Paying Agents
 
shall hold
 
available for
 
inspection or
 
collection at
 
their
 
specified office
during
 
normal
 
business
 
hours
 
copies
 
of
 
all
 
documents
 
required
 
to
 
be
 
so
 
available
 
by
 
the
Conditions of
 
any Notes. For
 
these purposes, the
 
Issuer,
 
failing which the
 
Guarantor,
 
shall
furnish the Paying Agents with sufficient copies of each of the relevant documents.
14.2
 
Each Paying Agent shall provide by email
 
to a Noteholder copies of all
 
documents required
to
 
be so
 
available by
 
the
 
Conditions of
 
any Notes,
 
following the
 
Noteholder’s prior
 
written
request and
 
provision of proof
 
of holding
 
and identity (in
 
a form
 
satisfactory to the
 
relevant
Paying Agent).
15.
 
MEETINGS OF NOTEHOLDERS
15.1
 
The
 
provisions of
 
hereto shall
 
apply to
 
meetings of
 
the
 
Noteholders and
 
shall
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have effect in the same manner as if set out in this Agreement.
15.2
 
Without prejudice to subclause
 
each of the Agent and the other Paying
 
Agents on the
request
 
of
 
any
 
Noteholder
 
shall
 
issue
 
voting
 
certificates
 
and
 
block
 
voting
 
instructions
 
in
accordance
 
with
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and
 
shall
 
forthwith
 
give
 
notice
 
to
 
the
 
Issuer
 
in
 
writing
 
of
 
any
 
revocation
 
or
amendment
 
of a
 
block voting
 
instruction.
 
Each of
 
the Agent
 
and the
 
other Paying
 
Agents
will
 
keep
 
a
 
full
 
and
 
complete
 
record
 
of
 
all
 
voting
 
certificates
 
and
 
block
 
voting
 
instructions
issued by it and will, not less than 24
 
hours before the time appointed for holding a meeting
or
 
adjourned meeting,
 
deposit at
 
such place
 
as the
 
Agent shall
 
designate or
 
approve, full
particulars
 
of
 
all
 
voting
 
certificates
 
and
 
block
 
voting
 
instructions
 
issued
 
by
 
it
 
in
 
respect
 
of
such
 
meeting
 
or
 
adjourned
 
meeting.
 
The
 
Issuer
 
shall
 
provide
 
to
 
the
 
Agent
 
sufficient
supplies of such voting certificates and block voting instructions
 
for such purposes.
16.
 
COMMISSIONS, EXPENSES
 
AND REVIEW OF FEES
 
AND EXPENSES
16.1
 
The
 
Issuer,
 
failing
 
which
 
the
 
Guarantor
 
agrees
 
to
 
pay
 
to
 
the
 
Agent
 
such
 
fees
 
and
commissions as
 
the Issuer,
 
the Guarantor
 
and the
 
Agent shall
 
separately agree
 
in respect
of
 
the
 
services
 
of
 
the
 
Agent
 
and
 
the
 
other
 
Paying
 
Agents
 
hereunder
 
together
 
with
 
any
expenses reasonably incurred (including
 
legal, printing, postage, fax,
 
cable and advertising
expenses) incurred by
 
the Agent and
 
the other Paying
 
Agents in connection
 
with their said
services.
16.2
 
The
 
Agent
 
will
 
make
 
payment
 
of
 
the
 
fees
 
and
 
commissions
 
due
 
hereunder
 
to
 
the
 
other
Paying
 
Agents and
 
will reimburse
 
their expenses
 
promptly after
 
the receipt
 
of the
 
relevant
moneys from the
 
Issuer or,
 
as the case
 
may be, the
 
Guarantor.
 
Neither the Issuer
 
nor the
Guarantor shall be responsible for any such payment
 
or reimbursement by the Agent to the
other Paying Agents.
16.3
 
The
 
parties
 
to
 
this
 
Agreement
 
agree
 
that,
 
at
 
the
 
request
 
of
 
the
 
Agent,
 
the
 
fees
 
and
expenses payable under this clause
 
may be reviewed and increased from time to time in
accordance with
 
the
 
Agent’s
 
or any
 
other relevant
 
Paying Agent’s
 
then
 
current fee
 
levels.
In
 
addition,
 
the
 
Agent
 
reserves
 
the
 
right
 
at
 
any
 
time
 
and
 
from
 
time
 
to
 
time
 
to
 
charge
 
the
Issuer properly incurred additional
 
fees and expenses
 
in respect of the
 
performance by the
Agent or
 
such other
 
Paying Agent
 
of services
 
hereunder in
 
respect of
 
any exercise
 
by the
Issuer
 
or
 
the
 
Noteholders
 
of
 
any
 
call
 
or
 
put
 
option,
 
exchanges, conversions,
 
solicitations,
offers, tenders or any other process that requires communication with
 
the Noteholders.
17.
 
INDEMNITY
17.1
 
The
 
Issuer,
 
failing
 
which
 
the
 
Guarantor,
 
agrees
 
to
 
indemnify,
 
defend
 
and
 
hold
 
the
 
Agent
and its
 
officers, directors,
 
employees, agents and
 
shareholders harmless from
 
and against
any and all liabilities that are properly incurred by each of them and
 
their respective officers,
directors,
 
employees,
 
agents
 
and
 
shareholders
 
arising
 
directly
 
or
 
indirectly
 
out
 
of
 
or
 
in
connection with this Agreement (including value added
 
tax or similar tax pursuant to
 
clause
1.4
 
of
 
this
 
Agreement
 
and
 
stamp
 
and
 
other
 
documentary
 
taxes
 
and
 
duties
 
pursuant
 
to
clause 27 of this Agreement, but
 
excluding all other taxes), including, without limitation, any
payment made by
 
the Agent relying
 
on information received
 
by it
 
pursuant to clause
 
7 and
the legal
 
costs and
 
expenses as
 
such expenses
 
are incurred
 
(including, without
 
limitation,
the
 
expenses
 
of
 
any
 
experts,
 
counsel,
 
agents
 
or
 
other
 
professional
 
advisers)
 
of
investigating,
 
preparing
 
for
 
or
 
defending
 
itself
 
against
 
any
 
action,
 
claim
 
or
 
liability
 
in
connection
 
with
 
its
 
performance
 
hereunder.
 
In
 
no
 
event
 
however,
 
shall
 
the
 
Issuer
 
or
 
the
Guarantor be
 
obliged to
 
indemnify the
 
Agent and
 
keep the
 
Agent harmless
 
from any
 
fees,
expenses,
 
charges
 
and/or
 
liabilities
 
(i)
 
incurred by
 
the
 
Agent
 
as
 
a
 
result
 
of
 
its
 
own
 
fraud,
wilful misconduct
 
or negligence,
 
or (ii)
 
the reimbursement
 
of which
 
is governed
 
by another
clause of this Agreement.
17.2
 
The
 
indemnity set
 
out
 
above
 
shall
 
survive the
 
resignation
 
or
 
removal
 
of
 
the
 
Agent
 
or
 
any
termination or expiry of this Agreement
 
including any termination under any bankruptcy law
or similar.
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18.
 
REPAYMENT
 
BY THE AGENT
Upon the Issuer or,
 
as the case may be, the
 
Guarantor being discharged from its obligation
to
 
make
 
payments
 
in
 
respect
 
of
 
any
 
Notes
 
pursuant
 
to
 
the
 
relevant
 
Conditions,
 
and
provided
 
that
 
there
 
is
 
no
 
outstanding,
bona
 
fide
and
 
proper
 
claim
 
in
 
respect
 
of
 
any
 
such
payments, the
 
Agent shall
 
forthwith on
 
demand pay
 
to the
 
Issuer or,
 
as the
 
case may
 
be,
the Guarantor sums
 
equivalent to any
 
amounts paid to
 
it by the
 
Issuer or,
 
as the case
 
may
be, the Guarantor for the purposes of such payments.
19.
 
CONDITIONS OF APPOINTMENT
19.1
 
The Agent
 
shall be
 
entitled to
 
deal with money
 
paid to it
 
by the Issuer
 
or the Guarantor
 
for
the purpose of
 
this Agreement in
 
the same manner
 
as other money
 
paid to a
 
banker by its
customers except:
(a)
 
that it shall not exercise
 
any right of set-off, lien or similar
 
claim in respect
 
thereof;
(b)
 
as provided in subclause
 
below; and
(c)
 
that it shall not be
 
liable to account to the
 
Issuer or the Guarantor for any
 
interest
thereon.
19.2
 
In
 
acting
 
hereunder
 
and
 
in
 
connection
 
with
 
the
 
Notes,
 
the
 
Agent
 
and
 
the
 
other
 
Paying
Agents
 
shall
 
act
 
solely
 
as
 
agents
 
of
 
the
 
Issuer
 
and
 
the
 
Guarantor
 
and
 
will
 
not
 
thereby
assume
 
any
 
obligations
 
towards
 
or
 
relationship
 
of
 
agency
 
or
 
trust
 
for
 
or
 
with
 
any
 
of
 
the
owners or holders of the Notes, Coupons or Talons.
19.3
 
The Agent
 
and the
 
other Paying Agents
 
hereby undertake to
 
the Issuer
 
and the
 
Guarantor
to
 
perform
 
such
 
obligations
 
and
 
duties,
 
and
 
shall
 
be
 
obliged
 
to
 
perform
 
such
 
duties
 
and
only
 
such
 
duties
 
as
 
are
 
herein
 
(including
 
Schedule
 
8
 
in
 
the
 
case
 
of
 
the
 
Agent),
 
in
 
the
Conditions and in
 
the Procedures Memorandum
 
specifically set forth
 
and no implied
 
duties
or
 
obligations
 
shall
 
be
 
read
 
into
 
this
 
Agreement
 
or
 
the
 
Notes
 
against
 
the
 
Agent
 
and
 
the
other Paying
 
Agents.
 
Each of
 
the Paying
 
Agents (other
 
than the
 
Agent) agrees
 
that if
 
any
information
 
that
 
is
 
required
 
by
 
the
 
Agent
 
to
 
perform
 
the
 
duties
 
set
 
out
 
in
 
Schedule
 
8
becomes known to it, it will promptly provide such information to the Agent.
19.4
 
The Agent
 
may consult
 
with legal
 
and other
 
professional advisers
 
and the
 
opinion of
 
such
advisers
 
shall
 
be
 
full
 
and
 
complete
 
protection
 
in
 
respect
 
of
 
any
 
action
 
taken,
 
omitted
 
or
suffered hereunder in good faith and in accordance with the opinion of such advisers.
19.5
 
Each of the Agent and the other Paying Agents shall be protected and shall incur no liability
for
 
or
 
in
 
respect
 
of
 
any
 
action
 
taken,
 
omitted
 
or
 
suffered
 
in
 
reliance
 
upon
 
any
 
instruction,
request
 
or
 
order
 
from
 
the
 
Issuer
 
or
 
the
 
Guarantor
 
or
 
any
 
notice,
 
resolution,
 
direction,
consent,
 
certificate,
 
affidavit,
 
Note,
 
statement,
 
cable,
 
telex
 
or
 
other
 
paper
 
or
 
document
which it
 
reasonably believes
 
to be
 
genuine and
 
to have
 
been delivered,
 
signed or
 
sent by
the proper party or parties or upon written instructions from the
 
Issuer or the Guarantor.
19.6
 
Any of
 
the Agent
 
and the
 
other Paying
 
Agents and
 
their officers,
 
directors and
 
employees
may
 
become the
 
owner of,
 
or acquire
 
any interest
 
in, any
 
Notes, Coupons
 
or Talons
 
with
the same
 
rights that
 
it or
 
they would
 
have if
 
the Agent
 
or the
 
relevant other
 
Paying Agent,
as
 
the
 
case
 
may
 
be,
 
concerned
 
were
 
not
 
appointed
 
hereunder,
 
and
 
may
 
engage
 
or
 
be
interested in any financial or other transaction with the Issuer
 
or the Guarantor and may act
on,
 
or
 
as
 
depositary,
 
trustee
 
or
 
agent
 
for,
 
any
 
committee
 
or
 
body
 
of
 
holders
 
of
 
Notes
 
or
Coupons or in connection with any other obligations
 
of the Issuer or the Guarantor as freely
as if the Agent or
 
the relevant other Paying Agent, as the
 
case may be, were not appointed
hereunder.
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19.7
 
The
 
Issuer
 
and
 
the
 
Guarantor
 
shall
 
provide
 
the
 
Agent
 
with
 
a
 
certified
 
copy
 
of
 
the
 
list
 
of
persons authorised
 
to execute
 
documents and
 
take action
 
on its
 
behalf in
 
connection with
this
 
Agreement
 
and
 
shall
 
notify
 
the
 
Agent
 
immediately
 
in
 
writing
 
if
 
any
 
of
 
such
 
persons
ceases to
 
be so
 
authorised or
 
if any
 
additional person
 
becomes so
 
authorised together,
 
in
the
 
case
 
of
 
an
 
additional
 
authorised
 
person,
 
with
 
evidence
 
satisfactory
 
to
 
the
 
Agent
 
that
such person has been so authorised.
19.8
 
Notwithstanding any provision of
 
this Agreement to
 
the contrary,
 
the Agent shall
 
not in any
event
 
be
 
liable
 
for
 
indirect,
 
punitive
 
or
 
consequential
 
loss
 
or
 
damage
 
of
 
any
 
kind
whatsoever (including but not
 
limited to lost profits), whether
 
or not foreseeable, even if
 
the
Agent has been advised of the likelihood of such loss or damage and regardless of whether
the claim for loss or damage is made in negligence, for breach of contract
 
or otherwise.
19.9
 
Notwithstanding anything
 
to the
 
contrary in
 
the transaction
 
documents, the
 
Agent shall
 
not
be
 
liable
 
to
 
any
 
person
 
for
 
any
 
matter
 
or
 
thing
 
done
 
or
 
omitted
 
in
 
any
 
way
 
in
 
connection
with the transaction documents save in relation to its own wilful default, negligence, fraud or
wilful misconduct, including that of its officers and employees.
19.10
 
The
 
Agent
 
shall
 
not
 
be
 
under
 
any
 
obligation
 
to
 
take
 
(and
 
the
 
Agent
 
shall
 
be
 
entitled
 
to
refrain
 
from
 
taking
 
without
 
liability)
 
any
 
action
 
under
 
this
 
Agency
 
Agreement
 
(including
without limitation,
 
any legal
 
action or
 
proceedings under
 
or in
 
connection with
 
this Agency
Agreement)
 
or
 
the
 
other
 
transaction
 
documents
 
which
 
in
 
its
 
reasonable
 
opinion
 
may
 
be
illegal or
 
contrary to
 
any law
 
or regulation
 
applicable to
 
it (including,
 
without limitation,
 
the
laws
 
of
 
the
 
United
 
States
 
of
 
America
 
or
 
any
 
jurisdiction
 
forming
 
part
 
of
 
it
 
or
 
England
 
and
Wales
 
or
 
Luxembourg)
 
or
 
any
 
direction
 
or
 
regulation
 
of
 
any
 
agency
 
of
 
any
 
such
 
state
 
or
jurisdiction. The
 
Agent may
 
without liability do
 
anything which
 
is, in
 
its reasonable
 
opinion,
necessary to
 
comply with
 
any
 
such
 
law,
 
directive,
 
policy or
 
regulation.
 
In
 
such
 
event,
 
the
Agent shall, where legally permissible and reasonably practicable,
 
take all reasonable steps
to notify the Issuer that it has so refrained.
20.
 
RELEASE OF THE GUARANTOR
20.1
 
If the Guarantee terminates
 
and the Guarantor is
 
released from its
 
obligations in respect of
the
 
Notes
 
pursuant
 
to
 
Condition
 
2(c)
 
(
Termination
 
of
 
Guarantee
),
 
the
 
Guarantor
 
will
 
be
deemed
 
to
 
be
 
simultaneously
 
released
 
from
 
its
 
rights
 
and
 
obligations
 
as
 
the
 
Guarantor
under
 
this
 
Agreement
 
from
 
(and
 
including)
 
the
 
Guarantee
 
Termination
 
Date,
 
without
prejudice to any obligations which may have accrued prior to
 
that time, without the need for
any further act or thing to be done.
20.2
 
Pursuant
 
to
 
the
 
terms
 
of
 
Condition
 
2(c),
 
the
 
Issuer
 
shall
 
deliver
 
to
 
the
 
Agent
 
a
 
notice
 
of
such termination as soon as reasonably practicable after such
 
termination.
21.
 
COMMUNICATION
 
BETWEEN THE PARTIES
A copy
 
of all
 
communications relating to
 
the subject
 
matter of
 
this Agreement
 
between the
Issuer,
 
the Guarantor and the Noteholders or Couponholders and any of the Paying Agents
(other than the Agent) shall be sent to the Agent by the other
 
relevant Paying Agent.
22.
 
CHANGES IN AGENT
 
AND OTHER PAYING AGENTS
22.1
 
Each of the Issuer and the Guarantor agrees that, for so long as any Note is outstanding, or
until moneys
 
for the
 
payment of
 
all amounts
 
in respect
 
of all
 
outstanding Notes
 
have been
made available to
 
the Agent and
 
have been returned
 
to the Issuer
 
or, as
 
the case may
 
be,
the Guarantor as provided herein:
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(a)
 
so long
 
as any
 
Notes are
 
listed on
 
any Stock
 
Exchange, there
 
will at
 
all times
 
be a
Paying Agent (which may be the Agent) with a
 
specified office in such place as may
be
 
required
 
by
 
the
 
rules
 
and
 
regulations
 
of
 
the
 
relevant
 
Stock
 
Exchange
 
or
 
other
relevant authority;
(b)
 
there will at all times
 
be a Paying Agent with
 
a specified office outside Norway;
 
and
(c)
 
there will at all times be
 
an Agent.
In
 
addition, the
 
Issuer
 
and
 
the
 
Guarantor
 
shall
 
forthwith
 
appoint
 
a
 
Paying Agent
 
having
 
a
specified office in New York
 
City in the circumstances described in the second paragraph of
Condition
 
4(d).
 
Any
 
variation,
 
termination,
 
appointment
 
or
 
change
 
shall
 
only
 
take
 
effect
(other than in the case of insolvency (as provided in subclause
 
below), when it shall be
of immediate effect)
 
after not less
 
than 30 nor
 
more than 45
 
days' prior notice
 
thereof shall
have been given to the Noteholders in accordance with Condition
 
12.
22.2
 
The Agent
 
may (subject as
 
provided in
 
subclause
 
below) at any
 
time resign
 
as Agent
by giving
 
at least
 
90 days'
 
written notice
 
to the
 
Issuer
 
and the
 
Guarantor of
 
such intention
on its part, specifying the date on which its desired resignation
 
shall become effective.
22.3
 
The Agent
 
may (subject
 
as provided
 
in subclause
 
below) be
 
removed at
 
any time
 
by
the Issuer and the Guarantor on at least 30
 
days' notice by the filing with it of
 
an instrument
in writing signed on behalf of the Issuer and the Guarantor specifying such removal
 
and the
date when it shall become effective.
22.4
 
Any resignation under
 
subclause
 
or removal under
 
subclauses
 
or
 
shall only
take effect
 
upon the
 
appointment by
 
the Issuer
 
and the
 
Guarantor as
 
hereinafter provided,
of a
 
successor Agent and
 
(other than
 
in cases
 
of insolvency
 
of the
 
Agent) on
 
the expiry
 
of
the notice to be given
 
under clause
 
The Issuer and the Guarantor agree
 
with the Agent
that if, by the
 
day falling ten days before
 
the expiry of any
 
notice under subclause
 
the
Issuer and
 
the Guarantor
 
have not
 
appointed a
 
successor Agent,
 
then
 
the Agent
 
shall be
entitled,
 
on
 
behalf of
 
the
 
Issuer
 
and the
 
Guarantor to
 
appoint
 
as
 
a successor
 
Agent in
 
its
place a reputable financial institution of good
 
standing which the Issuer shall approve (such
approval not to be unreasonably withheld or delayed).
22.5
 
In case at
 
any time the Agent
 
resigns, or is removed,
 
or becomes incapable of
 
acting, or is
adjudged
 
bankrupt
 
or
 
insolvent,
 
or
 
files
 
a
 
voluntary
 
petition
 
in
 
bankruptcy
 
or
 
makes
 
an
assignment
 
for
 
the
 
benefit
 
of
 
its
 
creditors
 
or
 
consents
 
to
 
the
 
appointment
 
of
 
an
administrator,
 
liquidator or
 
administrative or
 
other receiver
 
of all
 
or a
 
substantial part
 
of its
property,
 
or
 
admits
 
in
 
writing
 
its
 
inability
 
to
 
pay
 
or
 
meet
 
its
 
debts
 
as
 
they
 
mature
 
or
suspends
 
payment
 
thereof,
 
or
 
if
 
any
 
order
 
of
 
any
 
court
 
is
 
entered
 
approving
 
any
 
petition
filed by or
 
against it under
 
the provisions of
 
any applicable bankruptcy or
 
insolvency law or
if
 
a
 
receiver of
 
it
 
or
 
of
 
all or
 
a
 
substantial part
 
of its
 
property is
 
appointed or
 
if
 
any
 
officer
takes
 
charge
 
or
 
control
 
of
 
it
 
or
 
of
 
its
 
property
 
or
 
affairs
 
for
 
the
 
purpose
 
of
 
rehabilitation,
conservation
 
or
 
liquidation,
 
a
 
successor
 
Agent,
 
which
 
shall
 
be
 
a
 
reputable
 
financial
institution
 
of
 
good
 
standing
 
may
 
be
 
appointed
 
by
 
the
 
Issuer
 
and
 
the
 
Guarantor
 
by
 
an
instrument in
 
writing filed
 
with the
 
successor Agent.
 
Upon the
 
appointment as
 
aforesaid of
a
 
successor
 
Agent
 
and
 
acceptance
 
by
 
the
 
latter
 
of
 
such
 
appointment
 
and
 
(other
 
than
 
in
case
 
of
 
insolvency
 
of
 
the
 
Agent
 
when
 
it
 
shall
 
be
 
of
 
immediate
 
effect)
 
upon
 
expiry
 
of
 
the
notice
 
to
 
be given
 
under clause
 
the
 
Agent so
 
superseded shall
 
cease to
 
be the
 
Agent
hereunder.
22.6
 
Subject to
 
subclause
 
the Issuer
 
and the
 
Guarantor may,
 
after prior
 
consultation with
the Agent, terminate
 
the appointment of
 
any of the
 
other Paying Agents
 
at any
 
time and/or
appoint one or more further other
 
Paying Agents by giving to the
 
Agent, and to the relevant
other Paying Agent at least
 
45 days' notice in writing to that effect (other than in the case of
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insolvency of the other Paying Agent).
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22.7
 
Subject
 
to
 
subclause
 
all
 
or
 
any
 
of
 
the
 
Paying
 
Agents
 
may
 
resign
 
their
 
respective
appointments hereunder
 
at
 
any time
 
by giving
 
the Issuer,
 
the Guarantor
 
and
 
the
 
Agent at
least 45 days' written notice to that effect.
22.8
 
Upon its resignation or
 
removal becoming effective, the
 
Agent or the relevant
 
Paying Agent:
(a)
 
shall forthwith transfer all moneys
 
held by it hereunder and, if
 
applicable, deliver the
records referred
 
to in
 
subclauses
 
and
 
to the
 
successor Agent hereunder;
and
(b)
 
shall
 
be
 
entitled
 
to
 
the
 
payment
 
by
 
the
 
Issuer,
 
failing
 
which
 
the
 
Guarantor
 
of
 
its
commissions, fees and expenses for the services theretofore rendered hereunder in
accordance with the terms of clause
22.9
 
Upon
 
its
 
appointment
 
becoming
 
effective,
 
a
 
successor
 
Agent
 
and
 
any
 
new
 
Paying
 
Agent
shall, without further
 
act, deed or
 
conveyance, become vested
 
with all the
 
authority,
 
rights,
powers, trusts, immunities, duties and obligations
 
of its predecessor or, as the case may be,
a Paying
 
Agent with
 
like effect
 
as if
 
originally named
 
as Agent
 
or (as
 
the
 
case may
 
be) a
Paying Agent hereunder.
22.10
 
If either the Issuer or Guarantor is required to withhold or deduct any FATCA
 
Withholding in
connection
 
with any
 
payments due
 
on the
 
Notes and
 
such FATCA
 
Withholding would
 
not
have arisen
 
but for
 
the Paying
 
Agent not
 
being or
 
having ceased
 
to be
 
a
 
person to
 
whom
payments are free from FATCA
 
Withholding, the Issuer or Guarantor
 
will be entitled, during
the
 
period
 
in
 
which
 
that
 
Paying
 
Agent
 
is
 
not
 
a
 
person
 
to
 
whom
 
payments
 
are
 
free
 
from
FATCA
 
Withholding,
 
to
 
terminate
 
the
 
Paying
 
Agent
 
with
 
10
 
days’
 
notice
 
and
 
such
termination will be effective from any such time specified in writing to such
 
Paying Agent.
23.
 
MERGER AND CONSOLIDATION
Any
 
corporation
 
into
 
which
 
the
 
Agent
 
or
 
any
 
other
 
Paying
 
Agent
 
may
 
be
 
merged
 
or
converted, or
 
any corporation with
 
which the
 
Agent or
 
any of the
 
other Paying Agents
 
may
be consolidated, or
 
any corporation resulting
 
from any
 
merger,
 
conversion or consolidation
to which the Agent or any
 
of the other Paying Agents shall
 
be a party,
 
or any corporation to
which
 
the
 
Agent
 
or
 
any
 
of
 
the
 
other
 
Paying
 
Agents
 
shall
 
sell
 
or
 
otherwise
 
transfer
 
all
 
or
substantially
 
all
 
the
 
assets
 
of
 
the
 
Agent
 
or
 
any other
 
Paying
 
Agent,
 
or
 
any
 
corporation to
which
 
the
 
Agent
 
or
 
any
 
other
 
Paying
 
Agent
 
shall
 
sell
 
or
 
otherwise
 
transfer
 
all
 
or
substantially
 
all
 
of
 
its
 
corporate
 
trust
 
business
 
shall,
 
on
 
the
 
date
 
when
 
such
 
merger,
conversion, consolidation
 
or transfer
 
becomes effective
 
and to
 
the extent
 
permitted by
 
any
applicable laws,
 
become the
 
successor Agent
 
or,
 
as the
 
case may
 
be, other
 
Paying Agent
under this
 
Agreement without
 
the execution
 
or filing
 
of any
 
paper or
 
any further
 
act on
 
the
part
 
of
 
the
 
parties
 
hereto,
 
unless
 
otherwise
 
required
 
by
 
the
 
Issuer
 
or
 
the
 
Guarantor,
 
and
after
 
the
 
said
 
effective
 
date
 
all
 
references
 
in this
 
Agreement to
 
the
 
Agent
 
or,
 
as the
 
case
may
 
be,
 
such
 
other
 
Paying Agent
 
shall
 
be
 
deemed
 
to
 
be
 
references
 
to
 
such
 
corporation.
Written
 
notice of
 
any such
 
merger,
 
conversion, consolidation
 
or
 
transfer shall
 
forthwith be
given to the Issuer and the Guarantor by the Agent or other Paying
 
Agent.
24.
 
NOTIFICATION OF CHANGES TO PAYING AGENTS
Following
 
receipt
 
of
 
notice
 
of
 
resignation
 
from
 
the
 
Agent
 
or
 
any
 
other
 
Paying
 
Agent
 
and
forthwith
 
upon
 
appointing
 
a
 
successor
 
Agent
 
or,
 
as
 
the
 
case
 
may
 
be,
 
further
 
or
 
other
Paying Agents or on giving notice to terminate the appointment of the Agent or, as the
 
case
may
 
be,
 
other
 
Paying
 
Agent,
 
the
 
Agent
 
(on
 
behalf
 
of
 
and
 
at
 
the
 
expense
 
of
 
the
 
Issuer,
failing which the Guarantor) shall give or
 
cause to be given not more than
 
45 days' nor less
than 30 days' notice thereof to the Noteholders in accordance with
 
the Conditions.
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25.
 
CHANGE OF SPECIFIED
 
OFFICE
If
 
the
 
Agent
 
or
 
any
 
other
 
Paying
 
Agent
 
determines
 
to
 
change
 
its
 
specified
 
office
 
it
 
shall
(after
 
having, in any such case other
 
than a change of specified office
 
within the same city,
obtained
 
the
 
prior
 
written
 
approval
 
of
 
the
 
Issuer
 
and
 
the
 
Guarantor
 
thereto)
 
give
 
to
 
the
Issuer,
 
the
 
Guarantor
 
and
 
(if
 
applicable)
 
the
 
Agent
 
written
 
notice
 
of
 
such
 
determination
giving the address of the new specified office which shall be in the same city and stating
 
the
date on which such change is to take effect, which shall not be less than 45 days
 
thereafter.
The
 
Agent
 
(on
 
behalf
 
of
 
the
 
Issuer,
 
failing
 
which
 
the
 
Guarantor)
 
but
 
at
 
its
 
own
 
expense)
shall within
 
15
 
days of
 
receipt of
 
such notice
 
(unless the
 
appointment of
 
the
 
Agent or
 
the
other relevant
 
Paying Agent,
 
as the
 
case may
 
be, is
 
to terminate
 
pursuant to clause
 
on
or prior
 
to the
 
date of
 
such change)
 
give or
 
cause to
 
be given
 
not more
 
than 45
 
days' nor
less than 30 days' notice thereof to the Noteholders in accordance
 
with the Conditions.
26.
 
NOTICES AND COMMUNICATION
26.1
 
Any notice or communication
 
given hereunder shall be
 
sufficiently given or served:
(a)
 
if
 
delivered
 
in
 
person
 
to
 
the
 
relevant
 
address
 
specified
 
on
 
the
 
signature
 
pages
hereof or such other
 
address as may be notified
 
by the recipient in
 
accordance with
this clause
 
and, if
 
so delivered,
 
shall be
 
deemed to
 
have been
 
delivered at
 
time of
receipt; or
(b)
 
if
 
by
 
email,
 
when
 
sent,
 
subject
 
to
 
no
 
delivery
 
failure
 
notification
 
being
 
received
 
by
the
 
sender
 
within
 
24
 
hours
 
of
 
the
 
time
 
of
 
sending,
 
to
 
the
 
relevant
 
email
 
address
specified
 
on
 
the
 
signature
 
pages
 
hereof
 
or
 
such
 
other
 
email
 
address
 
as
 
may
 
be
notified by the recipient in accordance with this clause; or
(c)
 
if sent
 
by facsimile
 
to the
 
relevant number
 
specified on
 
the signature
 
pages hereof
or
 
such
 
other
 
address
 
as
 
may
 
be
 
notified
 
by
 
the
 
recipient
 
in
 
accordance
 
with
 
this
clause
 
and,
 
if
 
so
 
sent,
 
shall
 
be
 
deemed
 
to
 
have
 
been
 
delivered
 
immediately
 
after
transmission provided such transmission is confirmed when an acknowledgement of
receipt is received.
26.2
 
Where a communication is
 
received after business hours it
 
shall be deemed to be
 
received
and become effective on the
 
next business day.
 
Every communication shall be irrevocable
save in respect of any manifest error therein.
26.3
 
In no
 
event shall
 
the Agent
 
or any
 
other entity
 
of The
 
Bank of
 
New York
 
Mellon Group
 
be
liable
 
for
 
any
 
losses
 
arising
 
to
 
the
 
Agent
 
or
 
any
 
other
 
entity
 
of
 
The
 
Bank
 
of
 
New
 
York
Mellon Group
 
receiving or transmitting any data from any Issuer, any
 
Authorised Person or
any party
 
to the
 
transaction via any
 
non-secure method of
 
transmission or
 
communication,
such as,
 
but without
 
limitation, by
 
facsimile or
 
email.
 
The parties
 
hereto accept
 
that some
methods of communication are not secure and the Agent
 
or any other entity of The Bank
 
of
New York
 
Mellon Group
 
shall incur
 
no liability
 
for receiving
 
Instructions via
 
any
 
such non-
secure
 
method.
 
The
 
Agent
 
or
 
any
 
other
 
entity
 
of
 
The
 
Bank
 
of
 
New
 
York
 
Mellon
 
Group
 
is
authorised
 
to
 
comply
 
with
 
and
 
rely
 
upon
 
any
 
such
 
notice,
 
Instructions
 
or
 
other
communications believed
 
by it
 
to
 
have been
 
sent or
 
given by
 
an Authorised
 
Person or
 
an
appropriate
 
party
 
to
 
the
 
transaction
 
(or
 
authorised
 
representative
 
thereof).
 
The
 
Issuer
 
or
authorised
 
officer
 
of
 
the
 
Issuer
 
shall
 
use
 
all
 
reasonable
 
endeavours
 
to
 
ensure
 
that
Instructions
 
transmitted to
 
the
 
Agent
 
or
 
any
 
other
 
entity
 
of
 
The
 
Bank of
 
New
 
York
 
Mellon
Group
 
pursuant
 
to
 
this
 
Agreement
 
are
 
complete
 
and
 
correct.
 
Any
 
Instructions
 
shall
 
be
conclusively
 
deemed
 
to
 
be
 
valid
 
Instructions
 
from
 
the
 
Issuer
 
or
 
authorised
 
officer
 
of
 
the
Issuer
 
to
 
the
 
Agent
 
or
 
any
 
other
 
entity
 
of
 
The
 
Bank
 
of
 
New
 
York
 
Mellon
 
Group
 
for
 
the
purposes of this Agreement.
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27.
 
TAXES AND STAMP DUTIES
The
 
Issuer,
 
failing
 
which
 
the
 
Guarantor,
 
agrees
 
to
 
pay
 
any
 
and
 
all
 
stamp
 
and
 
other
documentary
 
taxes
 
or
 
duties
 
which
 
may
 
be
 
payable
 
in
 
connection
 
with
 
the
 
execution,
delivery, performance and enforcement of this Agreement.
28.
 
CURRENCY INDEMNITY
If, under
 
any applicable law
 
and whether pursuant
 
to a
 
judgment being made
 
or registered
against
 
the
 
Issuer
 
and/or
 
the
 
Guarantor
 
or
 
in
 
the
 
liquidation,
 
insolvency
 
or
 
analogous
process of
 
the Issuer
 
and/or the
 
Guarantor or
 
for any
 
other reason,
 
any payment
 
under or
in connection
 
with this
 
Agreement is
 
made or
 
falls to
 
be satisfied
 
in a
 
currency (the
other
currency
)
 
other
 
than
 
that
 
in
 
which
 
the
 
relevant
 
payment
 
is
 
expressed
 
to
 
be
 
due
 
(the
required
 
currency
)
 
under
 
this
 
Agreement,
 
then,
 
to
 
the
 
extent
 
that
 
the
 
payment
 
(when
converted into the required currency
 
at the rate of
 
exchange on the date of
 
payment or,
 
if it
is not practicable for the
 
Agent or the relevant
 
other Paying Agent to purchase
 
the required
currency with
 
the other
 
currency on
 
the date
 
of payment,
 
at the
 
rate
 
of exchange
 
as soon
thereafter
 
as
 
it
 
is
 
practicable
 
for
 
it
 
to
 
do
 
so
 
or,
 
in
 
the
 
case
 
of
 
a
 
liquidation,
 
insolvency
 
or
analogous process
 
at the
 
rate of
 
exchange on
 
the latest
 
date permitted
 
by applicable
 
law
for
 
the
 
determination
 
of
 
liabilities
 
in
 
such
 
liquidation,
 
insolvency
 
or
 
analogous
 
process)
actually received by
 
the Agent
 
or the relevant
 
other Paying Agent
 
falls short of
 
the amount
due under
 
the terms
 
of this
 
Agreement, the
 
Issuer and
 
the Guarantor
 
jointly and
 
severally
undertake
 
that
 
they
 
shall,
 
as
 
a
 
separate
 
and
 
independent
 
obligation,
 
indemnify
 
and
 
hold
harmless the Agent
 
and each other
 
Paying Agent against the
 
amount of such shortfall.
 
For
the
 
purpose
 
of
 
this
 
clause,
rate
 
of
 
exchange
means
 
the
 
rate
 
at
 
which
 
the
 
Agent
 
or
 
the
relevant other Paying
 
Agent is able
 
on the relevant
 
date to purchase
 
the required currency
with
 
the
 
other
 
currency
 
and
 
shall
 
take
 
into
 
account
 
any
 
premium
 
and
 
other
 
costs
 
of
exchange.
29.
 
AMENDMENTS
This
 
Agreement
 
may
 
be
 
amended
 
in
 
writing
 
by
 
agreement
 
between
 
the
 
Issuer,
 
the
Guarantor,
 
the
 
Agent
 
and
 
the
 
other
 
Paying
 
Agents,
 
but
 
without
 
the
 
consent
 
of
 
any
Noteholder
 
or
 
Couponholder,
 
for
 
the
 
purpose
 
of
 
curing
 
any
 
ambiguity
 
or
 
of
 
curing,
correcting
 
or
 
supplementing
 
any
 
defective
 
provision
 
contained
 
herein
 
or
 
in
 
any
 
manner
which
 
the
 
parties
 
may
 
mutually
 
deem
 
necessary
 
or
 
desirable
 
and
 
which
 
shall
 
not
 
be
materially prejudicial to the interests of the Noteholders.
 
The Issuer, the Guarantor and the
Agent may also agree any modification pursuant to
 
Condition 13 of the Notes.
30.
 
DESCRIPTIVE HEADINGS
The descriptive headings in this Agreement are for convenience of reference
 
only and shall
not define or limit the provisions hereof.
31.
 
CONTRACT (RIGHTS OF
 
THIRD PARTIES) ACT 1999
A
 
person
 
who
 
is
 
not
 
a
 
party
 
to
 
this
 
Agency
 
Agreement
 
or
 
any
 
agency
 
agreement
supplemental hereto has
 
no right
 
under the Contracts
 
(Rights of
 
Third Parties) Act
 
1999 to
enforce any term of this Agency Agreement or any agency agreement supplemental hereto,
but this does not affect any right or
 
remedy of a third party which exists or is available apart
from that Act.
32.
 
GOVERNING LAW AND SUBMISSION
 
TO JURISDICTION
32.1
 
This
 
Agreement
 
and
 
any
 
non-contractual
 
obligations
 
arising
 
out
 
of
 
or
 
in
 
connection
with
 
it
 
are governed by, and shall be construed in accordance with, English law.
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32.2
 
The
 
courts
 
of
 
England are
 
to
 
have
 
exclusive jurisdiction
 
to
 
settle
 
any disputes
 
which may
arise of out of or in
 
connection with this Agreement (including a dispute relating to
 
any non-
contractual obligations arising
 
out of or
 
in connection with
 
this Agreement) and
 
accordingly
any
 
legal
 
action
 
or
 
proceedings
 
arising
 
out
 
of
 
or
 
in
 
connection
 
with
 
this
 
Agreement
(
Proceedings
)
 
(including
 
any
 
Proceedings
 
relating
 
to
 
any
 
non-contractual
 
obligations
arising
 
out
 
of
 
or
 
in
 
connection
 
with
 
this
 
Agreement)
 
may
 
be
 
brought
 
in
 
such
 
courts.
 
The
Issuer
 
irrevocably
 
submits
 
to
 
the
 
jurisdiction
 
of
 
such
 
courts
 
and
 
waives
 
any
 
objection
 
to
Proceedings
 
in
 
any
 
such
 
courts
 
whether
 
on
 
the
 
ground
 
of
 
venue
 
or
 
on
 
the
 
ground
 
that
Proceedings have been brought
 
in an inconvenient forum.
 
This submission is made
 
for the
benefit of each
 
of the Paying
 
Agents and, to the
 
extent allowed by
 
applicable law,
 
shall not
limit the right of any of them to take Proceedings in any other court of competent jurisdiction
nor
 
shall
 
the
 
taking
 
of
 
Proceedings
 
in
 
one
 
or
 
more
 
jurisdictions
 
preclude
 
the
 
taking
 
of
Proceedings in any other jurisdiction (whether concurrently or not).
The Issuer
 
and the
 
Guarantor irrevocably
 
appoints Equinor
 
UK Limited
 
(whose offices
 
are
at
 
the
 
date
 
of
 
this
 
Agreement
 
at
 
One
 
Kingdom
 
Street,
 
Paddington
 
Central,
 
London
 
W2
6BD)
 
as
 
their
 
authorised
 
agent
 
for
 
service
 
of
 
process
 
in
 
England.
 
If
 
for
 
any
 
reason
 
such
agent shall cease to
 
be such agent for
 
service of process, the Issuer
 
and/or the Guarantor,
as
 
the
 
case
 
may
 
be,
 
shall
 
forthwith,
 
on
 
request
 
of
 
the
 
Agent,
 
appoint
 
a
 
new
 
agent
 
for
service
 
of
 
process
 
in
 
England
 
and
 
deliver
 
to
 
the
 
Agent
 
a
 
copy
 
of
 
the
 
new
 
agent's
acceptance of
 
that appointment
 
within 30
 
days.
 
Nothing in
 
this Agreement
 
shall affect
 
the
right to serve process in any other manner permitted by law.
33.
 
COUNTERPARTS
33.1
 
This Agreement may
 
be executed
 
by any
 
one or
 
more of
 
the parties
 
hereto in
 
any number
of counterparts, each
 
of which shall
 
be deemed to
 
be an original,
 
but all
 
such counterparts
shall together constitute one and the same instrument.
34.
 
GENERAL
34.1
 
If
 
any
 
provision
 
in
 
or
 
obligation
 
under
 
this
 
Agreement
 
is
 
or
 
becomes
 
invalid,
 
illegal
 
or
unenforceable in
 
any respect
 
under the
 
law of
 
any jurisdiction, that
 
will not
 
affect or
 
impair
(i)
 
the
 
validity,
 
legality
 
or
 
enforceability
 
under
 
the
 
law
 
of
 
that
 
jurisdiction
 
of
 
any
 
other
provision in or obligation under this Agreement, and
 
(ii) the validity,
 
legality or enforceability
under the
 
law of
 
any other
 
jurisdiction of
 
that or
 
any other
 
provision in
 
or obligation
 
under
this Agreement.
35.
 
EU CONTRACTUAL RECOGNITION
 
OF BAIL-IN
Notwithstanding
 
and
 
to
 
the
 
exclusion
 
of
 
any
 
other
 
term
 
of
 
this
 
Agreement
 
or
 
any
 
other
agreements, arrangements, or
 
understanding between the
 
parties to
 
this Agreement,
 
each
of
 
the
 
parties
 
to
 
this
 
Agreement
 
acknowledges
 
and
 
accepts
 
that
 
a
 
BRRD
 
Liability
 
arising
under
 
this
 
Agreement
 
may
 
be
 
subject
 
to
 
the
 
exercise
 
of
 
Bail-in
 
Powers
 
by
 
the
 
Relevant
Resolution Authority, and acknowledges, accepts, and agrees to be bound by:
(a)
 
the effect
 
of the
 
exercise of
 
Bail-in Powers by
 
the Relevant
 
Resolution Authority in
 
relation
to
 
any
 
BRRD
 
Liability
 
of
 
any
 
BRRD
 
Entity
 
(a
Relevant
 
BRRD
 
Party
)
 
to
 
any
 
other
 
party
under
 
this
 
Agreement,
 
that
 
(without
 
limitation)
 
may
 
include
 
and
 
result
 
in
 
any
 
of
 
the
following, or some combination thereof:
(i)
 
the reduction of all,
 
or a portion, of the
 
BRRD Liability or outstanding
 
amounts due
thereon;
(ii)
 
the conversion of all,
 
or a portion, of
 
the BRRD Liability into
 
shares, other securities
or
 
other obligations of the Relevant BRRD Party or another person, and the issue to
0010155-0003327 UKO2:
 
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or
 
conferral
 
on
 
any
 
other
 
party
 
to
 
this
 
Agreement
 
of
 
such
 
shares,
 
securities
 
or
obligations;
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(iii)
 
the cancellation of any
 
BRRD Liability; and
(iv)
 
the
 
amendment or
 
alteration of
 
the
 
amounts due
 
in
 
relation to
 
any
 
BRRD
 
Liability,
including any interest, if applicable, thereon, or the
 
date on which any payments are
due, including by suspending payment for a temporary period; and
(b)
 
the
 
variation
 
of
 
the
 
terms
 
of
 
this
 
Agreement
 
as
 
deemed
 
necessary
 
by
 
the
 
Relevant
Resolution Authority, to give effect to the exercise of Bail-in Powers by the Relevant
Resolution Authority.
For the purposes of this
 
clause
Bail-in
 
Legislation
means, in
 
relation to
 
a member
 
state of
 
the European
 
Economic Area
which
 
has
 
implemented,
 
or
 
which
 
at
 
any
 
time
 
implements,
 
the
 
BRRD,
 
the
 
relevant
implementing law,
 
regulation, rule or requirement as
 
described in the EU Bail-in
 
Legislation
Schedule from time to time;
Bail-in Powers
means any Write-down
 
and Conversion Powers
 
as defined in
 
the EU Bail-
in Legislation Schedule, in relation to the relevant Bail-in Legislation;
BRRD
means
 
Directive
 
2014/59/EU
 
of
 
15
 
May
 
2014
 
establishing
 
the
 
framework
 
for
 
the
recovery and resolution of
 
credit institutions and investment firms,
 
as amended or replaced
from time to time;
BRRD Entity
means any party to
 
this Agreement that is subject
 
to Bail-in Powers;
BRRD Liability
means any
 
liability in respect
 
of which the
 
relevant Bail-in
 
Powers may be
exercised;
EU
 
Bail-in
 
Legislation Schedule
means the
 
document described
 
as such,
 
then in
 
effect,
and published by the Loan Market Association (or any successor person) from time to time;
and
Relevant
 
Resolution
 
Authority
means,
 
in
 
respect
 
of
 
any
 
Relevant
 
BRRD
 
Party,
 
the
resolution
 
authority
 
with
 
the
 
ability
 
to
 
exercise
 
any
 
Bail-in
 
Powers
 
in
 
relation
 
to
 
such
Relevant BRRD Party.
IN
 
WITNESS
 
WHEREOF
the
 
parties
 
hereto
 
have
 
executed
 
this
 
Agreement
 
as
 
of
 
the
 
date
 
first
above written.
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43
SCHEDULE 1
TERMS AND CONDITIONS
 
OF THE NOTES OTHER
 
THAN VPS NOTES
The following are the Terms
 
and Conditions of the Notes other than VPS Notes which will be
incorporated by
 
reference into
 
each global
 
Note and
 
each definitive
 
Note, in
 
the latter
 
case
only if permitted by the relevant stock exchange or listing authority (if any) and agreed by the
Issuer and the
 
relevant Dealer at
 
the time of
 
issue but, if
 
not so permitted
 
and agreed, such
definitive Note
 
will have
 
endorsed thereon
 
or attached
 
thereto such
 
Terms
 
and Conditions.
The
 
applicable
 
Final
 
Terms
 
(or
 
the
 
relevant
 
provisions
 
thereof)
 
will
 
be
 
endorsed
 
upon,
 
or
attached
 
to,
 
each
 
temporary
 
global
 
Note,
 
permanent
 
global
 
Note
 
and
 
definitive
 
Note.
Reference should be made to "Form of Final Terms" above for a description of the content of
Final Terms
 
which will
 
include certain
 
terms used
 
in the
 
following Terms
 
and Conditions
 
or
specify which of such terms are to apply in relation to the relevant Notes.
This Note is one of a Series (as defined
 
below) of Notes issued by Equinor ASA (the
Issuer
)
pursuant to the Agency Agreement (as defined below).
References
 
herein
 
to
 
the
Notes
shall
 
be
 
references
 
to
 
the
 
Notes
 
of
 
this
 
Series
 
and
 
shall
mean:
(i)
 
in
 
relation
 
to
 
any
 
Notes
 
represented
 
by
 
a
 
global
 
Note,
 
units
 
of
 
each
 
Specified
Denomination in the Specified Currency;
(ii)
 
definitive Notes issued in
 
exchange for a
 
global Note; and
(iii)
 
any global Note.
The
 
Notes
 
and
 
the
 
Coupons (as
 
defined
 
below)
 
also
 
have
 
the
 
benefit
 
of
 
an
 
amended
 
and
restated
 
Agency
 
Agreement
 
(such
 
Agency
 
Agreement,
 
as
 
modified
 
and/or
 
restated
 
and/or
supplemented
 
from
 
time
 
to
 
time,
 
the
Agency
 
Agreement
)
 
dated
 
9
 
May
 
2022
 
and
 
made
among
 
the
 
Issuer,
 
Equinor
 
Energy
 
AS
 
(the
Guarantor
),
 
The
 
Bank
 
of
 
New
 
York
 
Mellon,
London
 
Branch
 
as
 
issuing
 
and
 
principal
 
paying
 
agent
 
and
 
agent
 
bank
 
(the
Agent
,
 
which
expression
 
shall
 
include
 
any
 
successor
 
agent
 
specified
 
in
 
the
 
applicable
 
Final
 
Terms)
 
and
the other
 
paying agents named
 
therein (together with
 
the Agent,
 
the
Paying Agents
, which
expression shall include any additional or successor paying agents).
If
 
so
 
indicated
 
in
 
the
 
applicable
 
Final
 
Terms,
 
the
 
Notes
 
will
 
(subject
 
to
 
Condition
 
2(c)
(
Termination
 
of
 
Guarantee
))
 
have
 
the
 
benefit
 
of
 
the
 
deed
 
of
 
guarantee
 
executed
 
by
 
the
Guarantor (such
 
deed
 
as modified
 
and/or restated
 
and/or
 
supplemented from
 
time
 
to
 
time,
the
Guarantee
) dated 13 May 2020.
Interest bearing definitive
 
Notes have interest
 
coupons (
Coupons
) and in
 
the case of
 
Notes
which, when issued in definitive form, have more than 27 interest payments remaining talons
for
 
further
 
Coupons
 
(
Talons
)
 
attached
 
on
 
issue.
 
Any
 
reference
 
herein
 
to
 
Coupons
 
or
coupons
 
shall,
 
unless the
 
context
 
otherwise requires,
 
be
 
deemed to
 
include a
 
reference to
Talons
 
or talons.
The final
 
terms for
 
this Note
 
(or the
 
relevant provisions
 
thereof) are
 
set out
 
in Part
 
A of
 
the
Final
 
Terms
 
attached
 
to
 
or
 
endorsed
 
on
 
this
 
Note
 
and
 
complete
 
these
 
Terms
 
and
Conditions. References
 
to the
applicable Final
 
Terms
are to
 
Part A
 
of the
 
Final Terms
 
(or
the relevant provisions thereof) attached to or endorsed on this
 
Note.
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Any reference
 
to
Noteholders
shall mean
 
the holders
 
of the
 
Notes, and
 
shall, in
 
relation to
any
 
Notes
 
represented
 
by
 
a
 
global
 
Note,
 
be
 
construed
 
as
 
provided
 
below.
 
Any
 
reference
herein
 
to
Couponholders
shall
 
mean
 
the
 
holders
 
of
 
any
 
Coupons,
 
and
 
shall,
 
unless
 
the
context otherwise requires, include the holders of any Talons.
As used
 
herein,
Tranche
means all
 
Notes with
 
the same
 
Issue Date
 
and which
 
are subject
to
 
the
 
same
 
Final
 
Terms
 
and
Series
means
 
a
 
Tranche
 
of
 
Notes
 
together
 
with
 
any
 
further
Tranche
 
or Tranches
 
of Notes
 
which are (i)
 
expressed to
 
be consolidated and
 
form a
 
single
series and (ii) identical in all respects (including as to listing and admission to trading) except
for their respective Issue Dates, Interest Commencement Dates and/or
 
Issue Prices.
The Noteholders and the
 
Couponholders are entitled to
 
the benefit of
 
the Deed of
 
Covenant
(such
 
Deed
 
of
 
Covenant,
 
as
 
modified
 
and/or
 
restated
 
and/or
 
supplemented
 
from
 
time
 
to
time, the
Deed
 
of
 
Covenant
)
 
dated 13
 
May 2020
 
and made
 
by the
 
Issuer.
 
The original
 
of
the
 
Deed
 
of
 
Covenant
 
is
 
held
 
by
 
a
 
common
 
depositary
 
on
 
behalf
 
of
 
Euroclear
 
(as
 
defined
below) and Clearstream, Luxembourg (as defined below).
Copies of
 
the Agency
 
Agreement and
 
the Deed
 
of Covenant
 
(i) are
 
available for
 
inspection
or
 
collection during
 
normal business
 
hours at
 
the
 
specified
 
office
 
of
 
each of
 
the
 
Agent and
the other Paying Agents or (ii)
 
may be provided by email to
 
a Noteholder following their prior
written request to the
 
Agent or any other
 
Paying Agent and provision of
 
proof of holding and
identity
 
(in
 
a form
 
satisfactory to
 
the
 
Agent
 
or
 
the
 
relevant
 
Paying Agent,
 
as the
 
case may
be). When
 
the Notes
 
are to
 
be admitted
 
to trading
 
on the
 
main market
 
of the
 
London Stock
Exchange
 
plc,
 
the
 
applicable
 
Final
 
Terms
 
will
 
be
 
published
 
on
 
the
 
website
 
of
 
the
 
London
Stock
 
Exchange
 
plc
 
through
 
a
 
regulatory
 
information
 
service.
 
The
 
applicable
 
Final
 
Terms
will, during
 
normal business
 
hours, be
 
available for
 
viewing at
 
and copies
 
may be
 
obtained
from
 
the
 
registered
 
office
 
of
 
the
 
Issuer
 
and
 
from
 
the
 
specified
 
office
 
of
 
each
 
of
 
the
 
Paying
Agents
 
by
 
a
 
Noteholder
 
upon
 
such
 
Noteholder
 
producing
 
evidence
 
satisfactory
 
to
 
the
relevant Paying
 
Agent as
 
to its
 
holding of
 
such Notes
 
and its
 
identity.
 
The Noteholders
 
and
the
 
Couponholders are
 
deemed to
 
have notice
 
of,
 
and are
 
entitled to
 
the
 
benefit of,
 
all the
provisions of the
 
Agency Agreement and
 
the applicable Final
 
Terms
 
which are applicable
 
to
them.
Words
 
and
 
expressions
 
defined
 
in
 
the
 
Agency
 
Agreement
 
or
 
used
 
in
 
the
 
applicable
 
Final
Terms
 
shall have the same meanings where used in
 
these Terms
 
and Conditions unless the
context
 
otherwise
 
requires
 
or
 
unless
 
otherwise
 
stated
 
and
 
provided
 
that,
 
in
 
the
 
event
 
of
inconsistency
 
between
 
the
 
Agency
 
Agreement
 
and
 
the
 
applicable
 
Final
 
Terms,
 
the
applicable Final Terms will prevail.
1.
 
Form, Denomination and
 
Title
The Notes
 
are in
 
bearer form
 
and, in
 
the case
 
of definitive
 
Notes, serially
 
numbered, in
 
the
currency
 
(the
Specified
 
Currency
)
 
and
 
the
 
denominations
 
(the
Specified
Denomination(s)
)
 
specified
 
in
 
the
 
applicable
 
Final
 
Terms.
 
Notes
 
of
 
one
 
Specified
Denomination may not be exchanged for Notes of another Specified
 
Denomination.
This
 
Note
 
may
 
be
 
a
 
Fixed
 
Rate
 
Note,
 
a
 
Floating
 
Rate
 
Note,
 
a
 
Zero
 
Coupon
 
Note
 
or
 
a
combination
 
of
 
any
 
of
 
the
 
foregoing,
 
depending
 
upon
 
the
 
Interest
 
Basis
 
shown
 
in
 
the
applicable Final Terms.
Definitive Notes
 
are
 
issued with
 
Coupons attached,
 
unless they
 
are
 
Zero Coupon
 
Notes in
which case
 
references to
 
Coupons and
 
Couponholders in
 
these
 
Terms
 
and
 
Conditions are
not applicable.
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Subject
 
as set
 
out
 
below,
 
title to
 
the
 
Notes and
 
Coupons will
 
pass by
 
delivery.
 
The Issuer,
the Guarantor, and any Paying Agent may deem and treat the bearer of any Note or
 
Coupon
as
 
the
 
absolute
 
owner
 
thereof
 
(whether
 
or
 
not
 
overdue
 
and
 
notwithstanding
 
any
 
notice
 
of
ownership or
 
writing thereon
 
or notice
 
of any
 
previous loss
 
or theft
 
thereof) for
 
all purposes
but,
 
in
 
the
 
case
 
of
 
any
 
global
 
Note,
 
without
 
prejudice
 
to
 
the
 
provisions set
 
out
 
in
 
the
 
next
succeeding paragraph.
For so
 
long as any
 
of the Notes
 
is represented by
 
a global Note
 
held on behalf
 
of Euroclear
Bank
 
SA/NV
 
(
Euroclear
)
 
and/or
 
Clearstream
 
Banking
 
S.A.
 
(
Clearstream,
 
Luxembourg
)
each
 
person
 
(other
 
than
 
Euroclear
 
or
 
Clearstream, Luxembourg)
 
who
 
is
 
for
 
the
 
time
 
being
shown
 
in
 
the
 
records
 
of
 
Euroclear
 
or
 
of
 
Clearstream,
 
Luxembourg
 
as
 
the
 
holder
 
of
 
a
particular nominal
 
amount of
 
such Notes
 
(in which
 
regard any
 
certificate or
 
other document
issued
 
by
 
Euroclear
 
or Clearstream,
 
Luxembourg as
 
to
 
the
 
nominal amount
 
of
 
such
 
Notes
standing to the
 
account of any
 
person shall be
 
conclusive and binding
 
for all
 
purposes save
in
 
the
 
case
 
of
 
manifest
 
error)
 
shall
 
be
 
treated
 
by
 
the
 
Issuer,
 
the
 
Guarantor (in
 
the
 
case
 
of
Notes
 
having
 
the
 
benefit of
 
the
 
Guarantee),
 
the
 
Agent
 
and
 
any
 
other
 
Paying Agent
 
as
 
the
holder of such
 
nominal amount of
 
such Notes for
 
all purposes other
 
than with respect
 
to the
payment
 
of
 
principal or
 
interest on
 
such nominal
 
amount
 
of such
 
Notes, for
 
which purpose
the
 
bearer
 
of
 
the
 
relevant
 
global Note
 
shall be
 
treated
 
by the
 
Issuer,
 
the
 
Guarantor (in
 
the
case of
 
Notes having
 
the benefit
 
of the
 
Guarantee), the
 
Agent and
 
any other
 
Paying Agent
as the
 
holder of
 
such nominal
 
amount of
 
such Notes
 
in accordance
 
with and
 
subject to
 
the
terms of the relevant global Note and the expressions
Noteholder
and
holder of Notes
and
related expressions shall be construed accordingly.
 
Notes which are represented by a global
Note will be transferable only in accordance
 
with the rules and procedures for the
 
time being
of Euroclear or of Clearstream, Luxembourg, as the case may
 
be.
2.
 
Status of the Notes and
 
the Guarantee
(a)
 
Status of the Notes
The
 
Notes
 
and
 
the
 
relative
 
Coupons
 
(if
 
any)
 
constitute
 
unsecured
 
and
 
unsubordinated
obligations
 
of
 
the
 
Issuer
 
and
 
shall
 
at
 
all
 
times
 
rank
pari
 
passu
and
 
without
 
any
 
preference
among themselves.
 
The payment
 
obligations of
 
the Issuer
 
under the
 
Notes and
 
the relative
Coupons
 
(if
 
any)
 
shall,
 
save
 
for
 
such
 
exceptions
 
as
 
may
 
be
 
provided
 
by
 
applicable
legislation,
 
at
 
all
 
times
 
rank
 
at
 
least equally
 
with
 
all
 
its
 
other
 
present
 
and
 
future
 
unsecured
and unsubordinated obligations.
(b)
 
Status of Guarantee
The
 
obligations
 
of
 
the
 
Guarantor
 
under
 
the
 
Guarantee
 
constitute
 
unsecured
 
and
unsubordinated
 
obligations
 
of
 
the
 
Guarantor
 
and
 
shall
 
at
 
all
 
times
 
rank
pari
 
passu
and
without any
 
preference among
 
themselves and
 
(with the
 
exception of
 
obligations in
 
respect
of
 
national and
 
local taxes
 
and certain
 
other statutory
 
exceptions and
 
subject as
 
aforesaid)
at
 
least
 
equally
 
with
 
all
 
its
 
other
 
present
 
and
 
future
 
unsecured
 
and
 
unsubordinated
obligations.
(c)
 
Termination of Guarantee
(i)
 
The
 
Guarantee
 
shall
 
automatically
 
and
 
unconditionally
 
be
 
terminated
 
on
 
the
Guarantee
 
Termination
 
Date.
 
As
 
soon
 
as
 
reasonably
 
practicable
 
after
 
such
termination
 
(and
 
by
 
no
 
later
 
than
 
15
 
Business Days
 
(as
 
defined
 
in
 
Condition 3(b)(i)
(
Interest
 
Payment
 
Dates
))
 
after
 
the
 
Guarantee
 
Termination
 
Date),
 
the
 
Guarantor
 
or
the
 
Issuer
 
shall
 
provide
 
notice
 
of
 
such
 
termination
 
to
 
the
 
Noteholders
 
and
Couponholders in accordance with Condition 12 (
Notices
).
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For the purposes of
 
this Condition 2(c)(i):
Guarantee
 
Termination
 
Date
means the
 
first date
 
on which
 
the aggregate
 
amount
of
 
indebtedness
 
for
 
borrowed
 
money
 
for
 
which
 
the
 
Guarantor
 
is
 
an
 
obligor
 
(as
 
a
guarantor,
 
co-issuer
 
or
 
borrower)
 
does
 
not
 
exceed
 
10
 
per
 
cent.
 
of
 
the
 
aggregate
principal
 
amount
 
of
 
indebtedness
 
for
 
borrowed
 
money
 
of
 
the
 
Issuer
 
and
 
its
Subsidiaries (as defined
 
in Condition 8
 
(
Events of Default
)), on a
 
consolidated basis,
as of such time; and
the amount of the Guarantor's indebtedness for borrowed money shall not include (A)
any
 
Notes
 
subject
 
to
 
this
 
Condition
 
2(c)
 
(
Termination
 
of
 
Guarantee
),
 
(B)
 
any
 
other
debt the
 
terms of
 
which permit
 
the termination
 
of the
 
Guarantor's guarantee
 
of such
debt under similar circumstances, as long as the Guarantor's obligations in respect of
such other debt are terminated at substantially the same time as
 
the Guarantee, and
(C)
 
any
 
debt
 
that
 
is
 
being
 
refinanced
 
at
 
substantially
 
the
 
same
 
time
 
that
 
the
Guarantee
 
of
 
the
 
Notes
 
is
 
being
 
terminated,
provided
 
that
any
 
obligations
 
of
 
the
Guarantor in respect of the debt that is incurred in the refinancing shall be included in
the calculation of the Guarantor's indebtedness for borrowed money.
(ii)
 
For
 
the
 
avoidance
 
of
 
doubt,
 
the
 
Notes
 
may
 
not
 
be
 
declared
 
due
 
and
 
payable
pursuant
 
to
 
Condition
 
8(e)
 
(
Events
 
of
 
Default
)
 
as
 
a
 
result
 
of
 
the
 
Guarantee
 
being
terminated pursuant to this Condition 2(c) (
Termination of Guarantee
).
3.
 
Interest
(a)
 
Interest on Fixed Rate
 
Notes
Each Fixed Rate
 
Note bears interest from
 
(and including) the
 
Interest Commencement Date
at
 
the
 
rate(s)
 
per
 
annum
 
equal
 
to
 
the
 
Rate(s)
 
of
 
Interest
 
payable
 
in
 
arrear
 
on
 
the
 
Interest
Payment
 
Date(s)
 
in
 
each
 
year
 
and
 
on the
 
Maturity
 
Date
 
if
 
that
 
does
 
not fall
 
on
 
an
 
Interest
Payment Date.
If
 
the
 
Notes
 
are
 
in
 
definitive
 
form,
 
except
 
as
 
provided
 
in
 
the
 
applicable
 
Final
 
Terms,
 
the
amount
 
of
 
interest
 
payable on
 
each
 
Interest
 
Payment
 
Date in
 
respect
 
of
 
the
 
Fixed
 
Interest
Period
 
ending
 
on
 
(but
 
excluding)
 
such
 
date
 
will
 
amount
 
to
 
the
 
Fixed
 
Coupon
 
Amount.
Payments of interest on any Interest Payment Date will, if so specified in the applicable Final
Terms,
 
amount to the Broken Amount(s) so specified.
As used
 
in these
 
Conditions,
Fixed Interest
 
Period
means the
 
period from
 
(and including)
an Interest
 
Payment Date
 
(or the
 
Interest Commencement
 
Date) to
 
(but excluding)
 
the next
(or first) Interest Payment Date.
Except
 
in
 
the
 
case
 
of
 
Notes
 
in
 
definitive
 
form
 
where
 
a
 
Fixed
 
Coupon
 
Amount
 
or
 
Broken
Amount
 
is specified
 
in the
 
applicable Final
 
Terms,
 
interest shall
 
be calculated
 
in respect
 
of
any period by applying the Rate of Interest to:
(A)
 
in
 
the
 
case
 
of
 
Fixed
 
Rate
 
Notes
 
which
 
are
 
represented
 
by
 
a
 
Global
 
Note,
 
the
aggregate outstanding nominal amount
 
of the Fixed Rate
 
Notes represented by such
Global Note; or
(B)
 
in the case of Fixed Rate Notes in definitive form, the Calculation Amount,
and, in each case, multiplying such sum by the applicable
 
Day Count Fraction.
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The
 
resultant
 
figure
 
(including
 
after
 
application
 
of
 
any
 
Fixed
 
Coupon
 
Amount
 
or
 
Broken
Amount to the Calculation Amount in the case of Fixed Rate Notes in definitive form) shall be
rounded to the nearest
 
sub-unit of the relevant Specified
 
Currency,
 
half of any such sub-unit
being rounded upwards or otherwise in accordance with applicable
 
market convention.
Where the Specified Denomination of a Fixed Rate Note in definitive form is a
 
multiple of the
Calculation Amount, the amount of
 
interest payable in respect of
 
such Fixed Rate Note shall
be the product of
 
the amount (determined in
 
the manner provided above) for
 
the Calculation
Amount and the amount by which the Calculation Amount is multiplied to reach the Specified
Denomination,
 
without any further rounding.
In these Conditions,
Day Count
 
Fraction
means, in respect of
 
the calculation of an
 
amount
of interest in accordance with this Condition 3(a) (
Interest on Fixed Rate Notes
):
(i)
 
if "Actual/Actual (ICMA)"
 
is specified in the
 
applicable Final Terms:
(a)
 
in
 
the
 
case
 
of
 
Notes
 
where
 
the
 
number
 
of
 
days
 
in
 
the
 
relevant
 
period
 
from
(and including) the most recent Interest Payment Date (or, if none, the Interest
Commencement
 
Date)
 
to
 
(but
 
excluding)
 
the
 
relevant
 
payment
 
date
 
(the
Accrual
 
Period)
 
is
 
equal
 
to
 
or
 
shorter
 
than
 
the
 
Determination
 
Period
 
during
which
 
the
 
Accrual
 
Period
 
ends,
 
the
 
number
 
of
 
days
 
in
 
such
 
Accrual
 
Period
divided by the product of (1) the
 
number of days in such Determination Period
and
 
(2)
 
the
 
number
 
of
 
Determination
 
Dates
 
(as
 
specified
 
in
 
the
 
applicable
Final Terms)
 
that would occur in one calendar year; or
(b)
 
in
 
the
 
case
 
of
 
Notes
 
where
 
the
 
Accrual
 
Period
 
is
 
longer
 
than
 
the
Determination Period during which the Accrual Period ends, the sum
 
of:
(1)
 
the number of
 
days in such
 
Accrual Period falling
 
in the
 
Determination
Period in which the
 
Accrual Period begins divided by
 
the product of (x)
the
 
number of
 
days in
 
such Determination
 
Period and
 
(y) the
 
number
of
 
Determination
 
Dates
 
(as
 
specified
 
in
 
the
 
applicable
 
Final
 
Terms)
that would occur in one calendar year; and
(2)
 
the
 
number
 
of
 
days
 
in
 
such
 
Accrual
 
Period
 
falling
 
in
 
the
 
next
Determination Period divided
 
by the
 
product of (x)
 
the number of
 
days
in
 
such
 
Determination
 
Period
 
and
 
(y)
 
the
 
number
 
of
 
Determination
Dates that would occur in one calendar year; and
(ii)
 
if "30/360" is specified in the applicable Final Terms,
 
the number of days in the period
from (and
 
including) the
 
most recent
 
Interest Payment
 
Date (or,
 
if none,
 
the Interest
Commencement Date) to
 
(but excluding) the
 
relevant payment date
 
(such number of
days
 
being
 
calculated
 
on
 
the
 
basis
 
of
 
a
 
year
 
of
 
360
 
days
 
with
 
12
 
30-day
 
months)
divided by 360.
In these Conditions:
Determination Period
means each period from
 
(and including) a Determination
 
Date to but
excluding the
 
next Determination Date
 
(including, where
 
either the
 
Interest Commencement
Date or the final
 
Interest Payment Date is not
 
a Determination Date, the period
 
commencing
on the first
 
Determination Date prior to,
 
and ending on
 
the first Determination
 
Date following
after, such date); and
0010155-0003327 UKO2:
 
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sub-unit
means,
 
with
 
respect
 
to
 
any
 
currency
 
other
 
than
 
euro,
 
the
 
lowest
 
amount
 
of
 
such
currency that is available as legal tender
 
in the country of such currency and,
 
with respect to
euro, means one cent.
(b)
 
Interest on Floating
 
Rate Notes
(i)
Interest Payment
 
Dates
Each
 
Floating
 
Rate
 
Note
 
bears
 
interest
 
from
 
(and
 
including)
 
the
 
Interest
Commencement Date and such interest will be payable in arrear
 
on either:
(A)
 
the
 
Specified Interest
 
Payment
 
Date(s) (each
 
an
Interest
 
Payment
 
Date
)
 
in
each year specified in the applicable Final Terms; or
(B)
 
if no Specified Interest Payment Date(s) is/are specified in the applicable Final
Terms,
 
each date (each an
Interest Payment Date
) which falls the number of
months
 
or
 
other
 
period
 
specified
 
as
 
the
 
Specified
 
Period
 
in
 
the
 
applicable
Final Terms
 
after the
 
preceding Interest
 
Payment Date
 
or,
 
in the
 
case of
 
the
first Interest Payment Date, after the Interest Commencement Date.
Such
 
interest
 
will
 
be
 
payable
 
in
 
respect
 
of
 
each
 
Interest
 
Period
 
(which
 
expression,
shall,
 
in
 
these
 
Terms
 
and
 
Conditions,
 
mean
 
the
 
period
 
from
 
(and
 
including)
 
an
Interest
 
Payment
 
Date
 
(or
 
the
 
Interest
 
Commencement Date)
 
to
 
(but
 
excluding) the
next
 
(or
 
first)
 
Interest
 
Payment
 
Date
 
or
 
the
 
relevant
 
payment
 
date
 
if
 
the
 
Notes
become payable on a date other than an Interest Payment Date).
If
 
a
 
Business
 
Day
 
Convention
 
is
 
specified
 
in
 
the
 
applicable
 
Final
 
Terms
 
and
 
(x)
 
if
there is no
 
numerically corresponding day in
 
the calendar month
 
in which an
 
Interest
Payment Date
 
should occur
 
or (y)
 
if any
 
Interest Payment
 
Date would
 
otherwise fall
on a day which is
 
not a Business Day,
 
then, if the Business Day convention specified
is:
(1)
 
in
 
any
 
case
 
where
 
Specified
 
Periods
 
are
 
specified
 
in
 
accordance
 
with
Condition
 
3(b)(i)(B)
 
above,
 
the
 
Floating
 
Rate
 
Convention,
 
such
 
Interest
Payment
 
Date
 
(i)
 
in
 
the
 
case
 
of
 
(x)
 
above,
 
shall
 
be
 
the
 
last
 
day
 
that
 
is
 
a
Business
 
Day
 
in
 
the
 
relevant
 
month
 
and
 
the
 
provisions
 
of
 
shall
apply
mutatis mutandis
or (ii)
 
in the
 
case of
 
(y) above,
 
shall be
 
postponed to
the next day which
 
is a Business Day unless
 
it would thereby fall into
 
the next
calendar
 
month,
 
in
 
which
 
event
 
(A)
 
such
 
Interest
 
Payment
 
Date
 
shall
 
be
brought
 
forward
 
to
 
the
 
immediately
 
preceding
 
Business
 
Day
 
and
 
(B)
 
each
subsequent
 
Interest
 
Payment
 
Date
 
shall
 
be
 
the
 
last
 
Business
 
Day
 
in
 
the
month
 
which
 
falls
 
in
 
the
 
Specified
 
Period
 
after
 
the
 
preceding
 
applicable
Interest Payment Date occurred; or
(2)
 
the Following Business Day
 
Convention, such Interest Payment
 
Date shall be
postponed to the next day which is a Business Day; or
(3)
 
the Modified Following Business Day Convention, such Interest Payment Date
shall
 
be
 
postponed
 
to
 
the
 
next
 
day
 
which
 
is
 
a
 
Business Day
 
unless
 
it
 
would
thereby
 
fall
 
into
 
the
 
next
 
calendar
 
month,
 
in
 
which
 
event
 
such
 
Interest
Payment
 
Date
 
shall
 
be
 
brought
 
forward
 
to
 
the
 
immediately
 
preceding
Business Day; or
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(4)
 
the Preceding Business Day Convention, such Interest Payment Date shall be
brought forward to the immediately preceding Business Day.
In this Condition,
Business Day
means:
(A)
 
a
 
day
 
on
 
which
 
commercial
 
banks
 
and
 
foreign
 
exchange
 
markets
 
settle
payments
 
and
 
are
 
open
 
for
 
general
 
business
 
(including
 
dealing
 
in
 
foreign
exchange
 
and
 
foreign
 
currency
 
deposits)
 
in
 
any
 
Additional
 
Business
 
Centre
(other than TARGET2 System) specified in the applicable Final Terms;
(B)
 
if
 
TARGET2
 
System
 
is
 
specified
 
as
 
an
 
Additional
 
Business
 
Centre
 
in
 
the
applicable Final Terms,
 
a day on
 
which the Trans-European
 
Automated Real-
Time Gross
 
Settlement Express Transfer
 
(TARGET2)
 
System (the
TARGET2
System
) is open;
 
and
(C)
 
either
 
(1)
 
in
 
relation
 
to
 
any
 
sum
 
payable
 
in
 
a
 
Specified
 
Currency
 
other
 
than
euro, a
 
day on
 
which commercial
 
banks and
 
foreign exchange
 
markets settle
payments
 
and
 
are
 
open
 
for
 
general
 
business
 
(including
 
dealing
 
in
 
foreign
exchange and foreign currency deposits) in the principal financial centre of the
country of
 
the relevant
 
Specified Currency (which
 
if the
 
Specified Currency is
New Zealand
 
dollars shall
 
be Auckland)
 
or (2)
 
in relation
 
to any
 
sum payable
in euro, a day on which the TARGET2 System is open.
(ii)
Rate of Interest
The Rate
 
of Interest
 
payable from
 
time to
 
time in
 
respect of
 
Floating Rate
 
Notes will
be determined in the manner specified in the applicable Final
 
Terms.
(A)
 
ISDA Determination for
 
Floating Rate Notes
Where ISDA
 
Determination is
 
specified in
 
the applicable
 
Final Terms
 
as the
 
manner
in which the Rate of Interest is to be determined, the Rate of Interest for each Interest
Period
 
will
 
be
 
the
 
relevant
 
ISDA
 
Rate
 
plus
 
or
 
minus
 
(as
 
indicated
 
in
 
the
 
applicable
Final
 
Terms)
 
the
 
Margin
 
(if
 
any).
 
For
 
the
 
purposes
 
of
 
this
 
sub-paragraph
,
ISDA
Rate
for
 
an
 
Interest
 
Period
 
means
 
a
 
rate
 
equal
 
to
 
the
 
Floating
 
Rate
 
that
 
would
 
be
determined
 
by
 
the
 
Agent
 
or
 
the
 
Calculation
 
Agent,
 
as
 
applicable,
 
under
 
an
 
interest
rate swap transaction if the Agent or the Calculation Agent, as applicable, were acting
as Calculation
 
Agent (as
 
defined in
 
the ISDA
 
Definitions (as
 
defined below))
 
for that
swap
 
transaction
 
under
 
the
 
terms
 
of
 
an
 
agreement
 
incorporating
 
(i)
 
if
 
“2006
 
ISDA
Definitions”
 
is
 
specified
 
in
 
the
 
applicable Final
 
Terms,
 
the
 
2006
 
ISDA
 
Definitions as
amended
 
and
 
updated
 
as
 
at
 
the
 
Issue
 
Date
 
of
 
the
 
first
 
Tranche
 
of
 
the
 
Notes,
published by
 
the International
 
Swaps and
 
Derivatives Association, Inc.
 
(
ISDA
); or
 
(ii)
if
 
“2021
 
ISDA
 
Definitions”
 
is
 
specified
 
in
 
the
 
applicable
 
Final
 
Terms,
 
the
 
latest
version of the 2021 ISDA Interest
 
Rate Derivatives Definitions as at the Issue
 
Date of
the
 
first
 
Tranche
 
of
 
the
 
Notes,
 
published
 
by
 
ISDA
 
(together,
 
the
ISDA
 
Definitions
)
and under which:
(1)
 
the Floating Rate Option
 
is as specified in
 
the applicable Final
 
Terms;
(2)
 
the
 
Designated
 
Maturity,
 
if
 
applicable,
 
is
 
a
 
period
 
specified
 
in
 
the
 
applicable
Final Terms;
(3)
 
the relevant Reset Date
 
is the day
 
specified in the
 
applicable Final Terms;
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(4)
 
if
 
the
 
Floating
 
Rate
 
Option
 
is
 
an
 
Overnight
 
Floating
 
Rate
 
Option,
 
the
Overnight
 
Rate
 
Compounding Method
 
is
 
one
 
of the
 
following as
 
specified
 
in
the applicable Final Terms:
(A)
 
Compounding with
 
Lookback;
(B)
 
Compounding with Observation
 
Period Shift; or
(C)
 
Compounding with Lockout;
 
and
(5)
 
if the
 
Floating Rate Option
 
is a
 
Compounded Index Floating
 
Rate Option, the
Index Method is Compounded Index Method with Observation Period Shift, as
specified in the applicable Final Terms.
In connection with
 
the Overnight Rate
 
Compounding Method, references in
 
the ISDA
Definitions
 
to
 
numbers
 
or
 
other
 
items
 
specified
 
in
 
the
 
relevant
 
confirmation shall
 
be
deemed to be references
 
to the numbers or
 
other items specified for
 
such purpose in
the applicable Final Terms.
For the purposes of this sub-paragraph
 
(i)
Floating Rate
,
Floating Rate Option
,
Designated
 
Maturity
,
Reset
 
Date
,
Overnight
 
Floating
 
Rate
 
Option
,
Overnight
Rate
 
Compounding Method
,
Compounding with
 
Lookback
,
Compounding with
Observation
 
Period
 
Shift
,
Compounding
 
with
 
Lockout
,
Averaging
 
with
Lookback
,
Averaging
 
with
 
Observation
 
Period
 
Shift
,
Averaging
 
with
 
Lockout
,
Compounded
 
Index
 
Floating
 
Rate
 
Option
,
Index
 
Method
and
Compounded
Index
 
Method
 
with
 
Observation
 
Period
 
Shift
have
 
the
 
meanings
 
given
 
to
 
those
terms
 
in
 
the
 
ISDA
 
Definitions,
 
(ii)
 
the
 
definition
 
of
Banking
 
Day
in
 
the
 
ISDA
Definitions
 
shall
 
be
 
amended
 
to
 
insert
 
after
 
the
 
words
 
"are
 
open
 
for"
 
in
 
the
 
second
line, the
 
word "general"
 
and (iii)
Euro-zone
means the
 
region comprised
 
of Member
States
 
of the
 
European Union
 
that
 
adopt the
 
single currency
 
in accordance
 
with the
Treaty on European Union.
(B)
 
Screen Rate Determination
 
for Floating Rate
 
Notes – Term Rate
Where “Screen
 
Rate Determination” is
 
specified in the
 
applicable Final Terms
 
as the
manner in which the Rate of Interest is to be determined and “Term
 
Rate” is specified
in the applicable Final
 
Terms
 
to be “Applicable”, the
 
Rate of Interest for
 
each Interest
Period will, subject to Condition 3(b)(viii) (
Benchmark Discontinuation
) and subject as
provided below, be either:
(1)
 
the offered quotation;
 
or
(2)
 
the
 
arithmetic
 
mean
 
(rounded
 
if
 
necessary
 
to
 
the
 
fifth
 
decimal
 
place,
 
with
0.000005 being rounded upwards) of the offered quotations,
(expressed
 
as
 
a
 
percentage
 
rate
 
per
 
annum)
 
for
 
the
 
Reference
 
Rate
 
(being
 
either
EURIBOR
 
or
 
NIBOR
 
or
 
STIBOR,
 
in
 
each
 
case
 
for
 
the
 
relevant
 
currency
 
and/or
period, all as specified in the applicable Final Terms)
 
which appears or appear, as the
case
 
may
 
be,
 
on
 
the
 
Relevant
 
Screen
 
Page
 
(or
 
such
 
replacement
 
page
 
on
 
that
service
 
which
 
displays
 
the
 
information)
 
as
 
at
 
the
 
Specified
 
Time
 
on
 
the
 
Interest
Determination
 
Date
 
in
 
question
 
plus
 
or
 
minus
 
(as
 
indicated
 
in
 
the
 
applicable
 
Final
Terms)
 
the Margin
 
(if any),
 
all as
 
determined by
 
the Agent
 
or the
 
Calculation Agent,
as applicable. If five
 
or more of such
 
offered quotations are available on
 
the Relevant
Screen Page,
 
the highest
 
(or,
 
if there
 
is more
 
than one
 
such highest
 
quotation, one
0010155-0003327 UKO2:
 
2004375908.9
51
only
 
of
 
such
 
quotations)
 
and
 
the
 
lowest
 
(or,
 
if
 
there
 
is
 
more
 
than
 
one
 
such
 
lowest
quotation,
 
one
 
only
 
of
 
such
 
quotations)
 
shall
 
be
 
disregarded
 
by
 
the
 
Agent
 
or
 
the
Calculation Agent,
 
as applicable,
 
for the
 
purpose of
 
determining the
 
arithmetic mean
(rounded as provided above) of such offered quotations.
If,
 
other
 
than
 
in
 
the
 
circumstances
 
described
 
in
 
Condition
 
3(b)(viii)
 
(
Benchmark
Discontinuation
) below,
 
the Relevant Screen Page is not available
 
or if, in the case of
Condition 3(b)(ii)(B)(1), no such offered quotation appears or, in the case of Condition
3(b)(ii)(B)(2), fewer than three such
 
offered quotations appear,
 
in each case as at
 
the
time
 
specified
 
in
 
Condition
 
3(b)(ii)(B)
 
the
 
Agent
 
or
 
the
 
Calculation
 
Agent,
 
as
applicable,
 
shall
 
request
 
each
 
of
 
the
 
Reference
 
Banks
 
to
 
provide
 
the
 
Agent
 
or
 
the
Calculation
 
Agent,
 
as
 
applicable,
 
with
 
its
 
offered
 
quotation
 
(expressed
 
as
 
a
percentage
 
rate
 
per
 
annum)
 
for
 
the
 
Reference
 
Rate
 
at
 
approximately
 
the
 
Specified
Time on
 
the Interest Determination
 
Date in question.
 
If two
 
or more of
 
the Reference
Banks
 
provide
 
the
 
Agent
 
or
 
the
 
Calculation
 
Agent,
 
as
 
applicable,
 
with
 
such
 
offered
quotations, the
 
Rate of
 
Interest for
 
such Interest
 
Period shall
 
be the
 
arithmetic mean
(rounded
 
if
 
necessary
 
to
 
the
 
fifth
 
decimal
 
place
 
with
 
0.000005
 
being
 
rounded
upwards)
 
of
 
such
 
offered
 
quotations
 
plus
 
or
 
minus
 
(as
 
appropriate)
 
the
 
Margin
 
(if
any), all as determined by the Agent or the Calculation Agent, as applicable.
If
 
on
 
any
 
Interest
 
Determination
 
Date
 
one
 
only
 
or
 
none
 
of
 
the
 
Reference
 
Banks
provides
 
the
 
Agent
 
or
 
the
 
Calculation
 
Agent,
 
as
 
applicable,
 
with
 
such
 
offered
quotations
 
as
 
provided
 
in
 
the
 
preceding
 
paragraph,
 
the
 
Rate
 
of
 
Interest
 
for
 
the
relevant
 
Interest
 
Period
 
shall
 
be
 
the
 
rate
 
per
 
annum
 
which
 
the
 
Agent
 
or
 
the
Calculation Agent,
 
as applicable,
 
determines as
 
being the
 
arithmetic mean
 
(rounded
if necessary
 
to the
 
fifth decimal
 
place, with
 
0.000005 being
 
rounded upwards)
 
of the
rates, as communicated to (and at
 
the request of) the Agent or the
 
Calculation Agent,
as
 
applicable,
 
by
 
the
 
Reference
 
Banks
 
or
 
any
 
two
 
or
 
more
 
of
 
them,
 
at
 
which
 
such
banks
 
were
 
offered,
 
at
 
approximately
 
the
 
Specified
 
Time
 
on
 
the
 
relevant
 
Interest
Determination
 
Date,
 
deposits
 
in
 
the
 
Specified
 
Currency
 
for
 
a
 
period
 
equal
 
to
 
that
which
 
would
 
have
 
been used
 
for
 
the
 
Reference Rate
 
by
 
leading
 
banks in
 
the
 
Euro-
zone inter-bank
 
market (if
 
the Reference
 
Rate is
 
EURIBOR) or
 
the Norwegian
 
inter-
bank market (if
 
the Reference Rate
 
is NIBOR) or
 
the Stockholm inter-bank
 
market (if
the Reference Rate
 
is STIBOR) plus
 
or minus (as
 
appropriate) the Margin (if
 
any) or,
if fewer than
 
two of the
 
Reference Banks provide
 
the Agent or
 
the Calculation Agent,
as
 
applicable,
 
with
 
such
 
offered
 
rates,
 
the
 
offered
 
rate
 
for
 
deposits
 
in
 
the
 
Specified
Currency
 
for
 
a
 
period
 
equal
 
to
 
that
 
which
 
would
 
have
 
been
 
used
 
for
 
the
 
Reference
Rate,
 
or
 
the
 
arithmetic
 
mean
 
(rounded
 
as
 
provided
 
above)
 
of
 
the
 
offered
 
rates
 
for
deposits in
 
the Specified
 
Currency for
 
a period
 
equal to
 
that which
 
would have
 
been
used
 
for
 
the
 
Reference
 
Rate,
 
at
 
which,
 
at
 
approximately
 
the
 
Specified
 
Time
 
on
 
the
relevant Interest Determination Date, any one
 
or more banks (which bank
 
or banks is
or are in
 
the opinion of
 
the Issuer suitable for
 
such purpose) informs the
 
Agent or the
Calculation Agent, as applicable, it
 
is quoting to leading banks
 
in the Euro-zone inter-
bank market (if the Reference Rate is
 
EURIBOR) or the Norwegian inter-bank market
(if
 
the
 
Reference
 
Rate
 
is
 
NIBOR)
 
or
 
the
 
Stockholm
 
inter-bank
 
market
 
(if
 
the
Reference
 
Rate
 
is
 
STIBOR)
 
plus
 
or
 
minus
 
(as
 
appropriate)
 
the
 
Margin
 
(if
 
any),
provided
 
that,
 
if
 
the
 
Rate
 
of
 
Interest
 
cannot
 
be
 
determined
 
in
 
accordance
 
with
 
the
foregoing provisions of
 
this paragraph, the
 
Rate of Interest
 
shall be
 
determined as at
the last
 
preceding Interest Determination
 
Date (though substituting,
 
where a
 
different
Margin is
 
to be
 
applied to
 
the relevant
 
Interest Period
 
from that
 
which applied
 
to the
last
 
preceding
 
Interest
 
Period,
 
the
 
Margin
 
relating
 
to
 
the
 
relevant
 
Interest
 
Period,
 
in
place of the Margin relating to that last preceding Interest Period).
exhibit25p53i0
0010155-0003327 UKO2:
 
2004375908.9
52
Reference
 
Banks
means, in
 
the case
 
of Condition
 
3(b)(ii)(B)(1) above,
 
those banks
whose offered rates were
 
used to determine such
 
quotation when such quotation last
appeared
 
on
 
the
 
Relevant
 
Screen
 
Page
 
and,
 
in
 
the
 
case
 
of
 
Condition
 
3(b)(ii)(B)(2)
above, those
 
banks whose
 
offered quotations
 
last appeared
 
on the
 
Relevant Screen
Page when no fewer
 
than three such offered
 
quotations appeared, and in
 
each case,
as selected by the Issuer.
Specified
 
Time
means
 
11.00
 
a.m.
 
(Brussels
 
time)
 
if
 
the
 
Reference
 
Rate
 
is
EURIBOR,
 
11.00
 
a.m.
 
(Stockholm
 
time)
 
if
 
the
 
Reference
 
Rate
 
is
 
STIBOR
 
or
 
12.00
noon (Oslo time) if the Reference Rate is NIBOR.
(C)
Screen Rate Determination for Floating Rate Notes – Compounded Daily
 
SONIA –
Non-Index Determination
Where the
 
applicable Final
 
Terms
 
specifies: (1)
 
“Screen Rate
 
Determination” as
 
the
manner in
 
which the
 
Rate of
 
Interest is
 
to be
 
determined and “Overnight
 
Rate” to
 
be
“Applicable”; (2)
 
“Compounded Daily
 
SONIA” as
 
the Reference
 
Rate; and
 
(3) “Index
Determination” to
 
be “Not
 
Applicable”, the Rate
 
of Interest
 
for an
 
Interest Period will,
subject to Condition 3(b)(viii) (
Benchmark Discontinuation
) and as provided below, be
Compounded Daily SONIA Formula Rate
 
with respect to such
 
Interest Period plus or
minus (as indicated in the applicable Final Terms) the applicable Margin (if any).
As
 
used
 
in
 
these
 
Conditions,
Compounded
 
Daily
 
SONIA
 
Formula
 
Rate
means,
with
 
respect
 
to
 
an
 
Interest
 
Period,
 
the
 
rate
 
of
 
return
 
of
 
a
 
daily
 
compound
 
interest
investment during the Observation Period corresponding to such Interest Period (with
the
 
daily
 
SONIA
 
reference
 
rate
 
as
 
reference
 
rate
 
for
 
the
 
calculation
 
of
 
interest)
 
as
calculated
 
by
 
the
 
Agent
 
or
 
the
 
Calculation
 
Agent,
 
as
 
applicable,
 
as
 
at
 
the
 
relevant
Interest
 
Determination
 
Date,
 
in
 
accordance
 
with
 
the
 
following
 
formula
 
(and
 
the
resulting
 
percentage
 
will
 
be
 
rounded,
 
if
 
necessary,
 
to
 
the
 
fifth
 
decimal
 
place,
 
with
0.000005 being rounded upwards):
where:
d
is the number of calendar
 
days in:
(1)
 
where “Lag” is specified as the Observation Method in the applicable
Final Terms,
 
the relevant Interest Period; or
(2)
 
where “Observation Shift”
 
is specified as the Observation Method in
the applicable Final Terms, the relevant Observation Period;
d
o
is the number of London
 
Banking Days in:
(1)
 
where “Lag” is specified as the Observation Method in the applicable
Final Terms,
 
the relevant Interest Period; or
(2)
 
where “Observation Shift”
 
is specified as the Observation Method in
the applicable Final Terms, the relevant Observation Period;
0010155-0003327 UKO2:
 
2004375908.9
53
i
is
 
a
 
series
 
of
 
whole
 
numbers
 
from
 
one
 
to
 
d
o
,
 
each
 
representing
 
a
 
London
Banking
 
Day
 
in
 
chronological
 
order
 
from,
 
and
 
including,
 
the
 
first
 
London
Banking Day in:
(1)
 
where “Lag”
 
is specified
 
as the
 
Observation Method
 
in the
 
applicable
Final Terms,
 
the relevant Interest Period; or
(2)
 
where
 
“Observation
 
Shift”
 
is
 
specified
 
as
 
the
 
Observation
 
Method
 
in
the applicable Final Terms, the relevant Observation Period;
London Banking
 
Day
means any
 
day on
 
which commercial
 
banks are
 
open
for
 
general
 
business
 
(including
 
dealing
 
in
 
foreign
 
exchange
 
and
 
foreign
currency deposits) in London;
n
i
, for
 
any London
 
Banking Day "i",
 
means the
 
number of calendar
 
days from
(and
 
including)
 
such
 
London
 
Banking
 
Day
 
"i"
 
up
 
to
 
(but
 
excluding)
 
the
following London Banking Day;
Observation Period
means, in
 
respect of
 
an Interest
 
Period, the
 
period from
(and including)
 
the date
 
falling "p"
 
London Banking
 
Days prior
 
to the
 
first day
of such
 
Interest Period
 
to (but
 
excluding) the
 
date falling
 
"p" London
 
Banking
Days
 
prior
 
to
 
(1)
 
the
 
Interest
 
Payment
 
Date
 
for
 
such
 
Interest
 
Period
 
or
 
(2)
such earlier date, if any, on which the Notes become due and payable;
p
means:
(1)
 
where “Lag”
 
is specified
 
as the
 
Observation Method
 
in the
 
applicable
Final
 
Terms,
 
the
 
number
 
of
 
London
 
Banking
 
Days
 
specified
 
as
 
the
“Lag Period” in the applicable Final
 
Terms
 
(or, if no
 
such number is so
specified, five London Banking Days); or
(2)
 
where
 
“Observation
 
Shift”
 
is
 
specified
 
as
 
the
 
Observation
 
Method
 
in
the
 
applicable
 
Final
 
Terms,
 
the
 
number
 
of
 
London
 
Banking
 
Days
specified
 
as
 
the
 
“Observation
 
Shift
 
Period”
 
in
 
the
 
applicable
 
Final
Terms
 
(or,
 
if
 
no
 
such
 
number
 
is
 
so
 
specified,
 
five
 
London
 
Banking
Days);
SONIA reference rate
means, in respect of any London Banking Day (
LBD
x
),
a reference
 
rate equal
 
to the
 
daily Sterling Overnight
 
Index Average
 
(
SONIA
)
rate
 
for
 
LBD
x
as
 
provided
 
by
 
the
 
administrator
 
of
 
SONIA
 
to
 
authorised
distributors
 
and
 
as
 
then
 
published
 
on
 
the
 
Relevant
 
Screen
 
Page
 
(or,
 
if
 
the
Relevant
 
Screen
 
Page
 
is
 
unavailable,
 
as
 
otherwise
 
published
 
by
 
such
authorised
 
distributors)
 
on
 
the
 
London
 
Banking
 
Day
 
immediately
 
following
LBD
x
; and
SONIA
i
means the SONIA
 
reference rate for:
(1)
 
where “Lag”
 
is specified
 
as the
 
Observation Method
 
in the
 
applicable
Final
 
Terms,
 
the
 
London
 
Banking
 
Day
 
falling
 
"p"
 
London
 
Banking
Days prior to the relevant London Banking Day "i"; or
(2)
 
where
 
“Observation
 
Shift”
 
is
 
specified
 
as
 
the
 
Observation
 
Method
 
in
the applicable Final Terms, the relevant London Banking Day "i".
0010155-0003327 UKO2:
 
2004375908.9
54
If, where any Rate of Interest is to be calculated pursuant to
 
this Condition
,
in respect of any London Banking Day for which the SONIA reference rate is required
to be
 
determined, the
 
Agent or
 
the Calculation
 
Agent, as
 
applicable, determines that
the
 
applicable
 
SONIA
 
reference
 
rate
 
is
 
not
 
available
 
on
 
the
 
Relevant
 
Screen
 
Page
and
 
has
 
not
 
otherwise
 
been
 
published
 
by
 
the
 
relevant
 
authorised
 
distributors,
 
then
(unless
 
the
 
Agent
 
or
 
the
 
Calculation
 
Agent,
 
as
 
applicable,
 
has
 
been
 
notified
 
of
 
any
Successor
 
Rate
 
or
 
Alternative
 
Rate
 
(and
 
any
 
related
 
Adjustment
 
Spread
 
and/or
Benchmark
 
Amendments)
 
pursuant
 
to
 
Condition
 
3(b)(viii)
 
(
Benchmark
Discontinuation
),
 
if
 
applicable)
 
the
 
SONIA
 
reference
 
rate
 
in
 
respect
 
of
 
such
 
London
Banking Day shall be:
(1)
 
(I) the
 
Bank of
 
England’s Bank
 
Rate (the
Bank
 
Rate
) prevailing
 
at 5.00
 
p.m.
(London
 
time) (or,
 
if
 
earlier,
 
the
 
close
 
of
 
business) on
 
such London
 
Banking
Day; plus (II) the mean of the
 
spread of the SONIA reference rate to the Bank
Rate
 
over
 
the
 
previous
 
five
 
London
 
Banking
 
Days
 
on
 
which
 
a
 
SONIA
reference rate
 
has been
 
published, excluding
 
the highest
 
spread (or,
 
if there
is
 
more
 
than
 
one
 
highest
 
spread,
 
one
 
only
 
of
 
those
 
highest
 
spreads)
 
and
lowest spread
 
(or,
 
if there
 
is more
 
than one
 
lowest spread,
 
one only
 
of those
lowest spreads) to the Bank Rate; or
(2)
 
if the Bank Rate under (1)(I) above is not available at the relevant time, either
(I)
 
the
 
SONIA
 
reference
 
rate
 
published
 
on
 
the
 
Relevant
 
Screen
 
Page
 
(or
otherwise
 
published
 
by
 
the
 
relevant
 
authorised
 
distributors)
 
for
 
the
 
first
preceding
 
London
 
Banking
 
Day
 
on
 
which
 
the
 
SONIA
 
reference
 
rate
 
was
published
 
on
 
the
 
Relevant
 
Screen
 
Page
 
(or
 
otherwise
 
published
 
by
 
the
relevant
 
authorised
 
distributors)
 
or
 
(II)
 
if
 
this
 
is
 
more
 
recent,
 
the
 
latest
 
rate
determined under (1) above,
and,
 
in
 
each
 
case,
 
references
 
to
 
the
 
"SONIA
 
reference
 
rate"
 
in
 
this
 
Condition
 
shall be construed accordingly.
In
 
the
 
event
 
that
 
the
 
Rate
 
of
 
Interest
 
cannot
 
be
 
determined
 
in
 
accordance
 
with
 
the
foregoing
 
provisions,
 
the
 
Rate
 
of
 
Interest
 
shall
 
(subject
 
to
 
Condition
 
3(b)(viii)
(
Benchmark Discontinuation
)) be:
(1)
 
that determined
 
as at
 
the last
 
preceding Interest
 
Determination Date
 
(though
substituting,
 
where
 
a
 
different
 
Margin,
 
Maximum
 
Rate
 
of
 
Interest
 
and/or
Minimum Rate
 
of Interest is
 
to be
 
applied to the
 
relevant Interest Period
 
from
that which applied to the last
 
preceding Interest Period, the Margin, Maximum
Rate
 
of
 
Interest
 
and/or
 
Minimum
 
Rate
 
of
 
Interest
 
(as
 
the
 
case
 
may
 
be)
relating to the relevant
 
Interest Period, in place
 
of the Margin, Maximum
 
Rate
of Interest and/or Minimum Rate of Interest
 
(as applicable) relating to that last
preceding Interest Period); or
(2)
 
if
 
there
 
is
 
no
 
such
 
preceding
 
Interest
 
Determination
 
Date,
 
the
 
initial
 
Rate
 
of
Interest
 
which
 
would
 
have
 
been
 
applicable
 
to
 
such
 
Notes
 
for
 
the
 
first
scheduled
 
Interest
 
Period
 
had
 
the
 
Notes
 
been
 
in
 
issue
 
for
 
a
 
period
 
equal
 
in
duration
 
to
 
the
 
first
 
scheduled Interest
 
Period
 
but
 
ending on
 
(and
 
excluding)
the Interest Commencement
 
Date (but applying
 
the Margin and,
 
if applicable,
any Maximum Rate
 
of Interest and/or Minimum
 
Rate of Interest,
 
applicable to
the first scheduled Interest Period).
exhibit25p56i0
0010155-0003327 UKO2:
 
2004375908.9
55
If
 
the
 
Notes
 
become
 
due
 
and
 
payable
 
in
 
accordance
 
with
 
Condition
 
8
 
(
Events
 
of
Default
),
 
the
 
final
 
Rate
 
of
 
Interest
 
shall
 
be
 
calculated
 
for
 
the
 
period
 
from
 
(and
including)
 
the
 
previous
 
Interest
 
Payment
 
Date
 
to
 
(but
 
excluding)
 
the
 
date
 
on
 
which
the
 
Notes become
 
so
 
due and
 
payable,
 
and such
 
Rate
 
of
 
Interest
 
shall continue
 
to
apply to the
 
Notes for so
 
long as interest
 
continues to accrue
 
thereon as provided
 
in
Condition
 
(
Accrual of Interest
).
(D)
Screen Rate Determination for Floating Rate Notes – Compounded Daily
 
SONIA –
Index Determination
Where the
 
applicable Final
 
Terms
 
specifies: (1)
 
“Screen Rate
 
Determination” as
 
the
manner in
 
which the
 
Rate of
 
Interest is
 
to be
 
determined and
 
“Overnight Rate”
 
to be
“Applicable”; (2)
 
“Compounded Daily
 
SONIA” as
 
the
 
Reference Rate;
 
and (3)
 
“Index
Determination”
 
to
 
be
 
“Applicable”,
 
the
 
Rate
 
of
 
Interest
 
for
 
an
 
Interest
 
Period
 
will,
subject to Condition 3(b)(viii) (
Benchmark Discontinuation
) and as provided below,
 
be
the Compounded Daily SONIA Index Rate with respect to such Interest Period
 
plus or
minus (as indicated in the applicable Final Terms) the applicable Margin (if any).
Compounded
 
Daily
 
SONIA
 
Index
 
Rate
means, with
 
respect to
 
an Interest
 
Period,
the rate of
 
return of a
 
daily compound interest investment
 
as calculated by
 
the Agent
or the Calculation Agent, as applicable, on the relevant Interest Determination Date in
accordance with
 
the following formula
 
(and the
 
resulting percentage will
 
be rounded,
if necessary, to the fifth decimal place, with 0.000005 being rounded upwards):
where:
d
is
 
the
 
number
 
of
 
calendar
 
days from
 
(and
 
including)
 
the
 
day
 
in
 
relation
 
to
which SONIA
 
Compounded Index
Start
is determined
 
to (but
 
excluding) the day
in relation to which SONIA Compounded Index
End
is determined;
London Banking Day
has the meaning
 
set out in Condition
 
above;
Relevant
 
Number
is
 
the
 
number
 
specified
 
as
 
such
 
in
 
the
 
applicable
 
Final
Terms
 
(or, if no such number is specified, five);
SONIA
 
Compounded Index
End
means the
 
SONIA Compounded
 
Index value
relating
 
to
 
the
 
London
 
Banking
 
Day
 
falling
 
the
 
Relevant
 
Number
 
of
 
London
Banking Days
 
prior to
 
(1) the
 
Interest Payment
 
Date for
 
the
 
relevant Interest
Period
 
or
 
(2)
 
such
 
earlier
 
date,
 
if
 
any,
 
on
 
which
 
the
 
Notes
 
become
 
due
 
and
payable;
SONIA Compounded
 
Index
Start
means the
 
SONIA Compounded Index
 
value
relating
 
to
 
the
 
London
 
Banking
 
Day
 
falling
 
the
 
Relevant
 
Number
 
of
 
London
Banking Days prior to the first day of the relevant Interest Period; and
the
SONIA Compounded
 
Index
means, with respect
 
to any London
 
Banking
Day,
 
the
 
value
 
of
 
the
 
SONIA
 
compounded
 
index
 
that
 
is
 
provided
 
by
 
the
administrator
 
of
 
the
 
SONIA
 
reference
 
rate
 
to
 
authorised
 
distributors
 
and
 
as
then published on the Relevant Screen
 
Page (or, if
 
the Relevant Screen Page
is
 
unavailable,
 
as
 
otherwise
 
published
 
by
 
such
 
authorised
 
distributors)
 
in
respect of such London Banking Day.
exhibit25p57i0
0010155-0003327 UKO2:
 
2004375908.9
56
If, where any Rate of Interest is to be calculated pursuant to this
 
Condition
,
the
 
Agent
 
or
 
the
 
Calculation
 
Agent,
 
as
 
applicable,
 
determines
 
that
 
the
 
relevant
SONIA
 
Compounded
 
Index
 
value
 
required
 
to
 
determine
 
SONIA
 
Compounded
Index
Start
or
 
SONIA
 
Compounded
 
Index
End
is
 
not
 
available
 
on
 
the
 
Relevant
 
Screen
Page and has not otherwise
 
been published by the
 
relevant authorised distributors by
5.00 p.m.
 
(London time)
 
(or,
 
if later,
 
by the
 
time falling
 
one hour
 
after the
 
customary
or
 
scheduled
 
time
 
for
 
publication
 
thereof
 
in
 
accordance
 
with
 
the
 
then-prevailing
operational
 
procedures of
 
the
 
administrator
 
of
 
the
 
SONIA
 
reference
 
rate
 
or
 
of
 
such
other information service, as the case may
 
be) on the relevant Interest Determination
Date, the Compounded Daily SONIA Index
 
Rate for the applicable Interest
 
Period for
which
 
the
 
relevant
 
SONIA
 
Compounded
 
Index
 
value
 
is
 
not
 
available
 
shall
 
be
"Compounded Daily
 
SONIA Formula Rate"
 
determined in accordance
 
with Condition
 
above
 
as
 
if
 
Index
 
Determination
 
had
 
been
 
specified
 
as
 
being
 
Not
Applicable
 
in
 
the
 
applicable
 
Final
 
Terms,
 
and
 
for
 
these
 
purposes:
 
(1)
 
the
"Observation
 
Method"
 
shall
 
be
 
deemed
 
to
 
be
 
"Observation
 
Shift"
 
and
 
(2)
 
the
"Observation
 
Shift
 
Period"
 
shall
 
be
 
deemed
 
to
 
be
 
equal
 
to
 
the
 
Relevant
 
Number
 
of
London
 
Banking
 
Days,
 
as
 
if
 
those
 
alternative
 
elections
 
had
 
been
 
made
 
in
 
the
applicable Final Terms.
If
 
the
 
Notes
 
become
 
due
 
and
 
payable
 
in
 
accordance
 
with
 
Condition
 
8
 
(
Events
 
of
Default
),
 
the
 
final
 
Rate
 
of
 
Interest
 
shall
 
be
 
calculated
 
for
 
the
 
period
 
from
 
(and
including)
 
the
 
previous
 
Interest
 
Payment
 
Date
 
to
 
(but
 
excluding)
 
the
 
date
 
on
 
which
the
 
Notes
 
become so
 
due
 
and
 
payable,
 
and
 
such
 
Rate
 
of
 
Interest
 
shall
 
continue
 
to
apply to
 
the Notes
 
for so
 
long as
 
interest continues to
 
accrue thereon as
 
provided in
Condition
 
(
Accrual of Interest
).
(E)
Screen
 
Rate
 
Determination
 
for
 
Floating
 
Rate
 
Notes
 
–
 
Compounded
 
Daily
 
SOFR
 
–
Non-Index Determination
Where the
 
applicable Final
 
Terms
 
specifies: (1)
 
“Screen Rate
 
Determination” as
 
the
manner in
 
which the
 
Rate of
 
Interest is
 
to be
 
determined and
 
“Overnight Rate”
 
to be
“Applicable”;
 
(2)
 
“Compounded Daily
 
SOFR”
 
as
 
the
 
Reference
 
Rate;
 
and
 
(3)
 
“Index
Determination” to
 
be “Not
 
Applicable”, the Rate
 
of Interest
 
for an
 
Interest Period
 
will,
subject
 
to
 
Condition
 
(
Benchmark
 
Discontinuation
 
–
 
SOFR
)
 
and
 
as
 
provided
below,
 
be
 
Compounded
 
Daily
 
SOFR
 
Formula
 
Rate
 
with
 
respect
 
to
 
such
 
Interest
Period
 
plus
 
or
 
minus
 
(as
 
indicated
 
in
 
the
 
applicable
 
Final
 
Terms)
 
the
 
applicable
Margin (if any).
Compounded Daily SOFR
 
Formula Rate
means, with respect to an Interest Period,
the
 
rate
 
of
 
return
 
of
 
a
 
daily
 
compound
 
interest
 
investment
 
in
 
U.S.
 
dollars
 
(with
 
the
Secured
 
Overnight
 
Financing
 
Rate
 
as
 
the
 
reference
 
rate
 
for
 
the
 
calculation
 
of
interest)
 
as
 
calculated
 
by
 
the
 
Agent
 
or
 
the
 
Calculation Agent,
 
as
 
applicable,
 
on
 
the
relevant
 
Interest
 
Determination
 
Date
 
in
 
accordance
 
with
 
the
 
following
 
formula
 
(and
the
 
resulting
 
percentage
 
will
 
be
 
rounded,
 
if
 
necessary,
 
to
 
the
 
nearest
 
fifth
 
decimal
place, with 0.000005 being rounded upwards):
where:
d
is the number of calendar
 
days in:
0010155-0003327 UKO2:
 
2004375908.9
57
(1)
 
where
 
"Lookback"
 
or
 
“Lock-out”
 
is
 
specified
 
as
 
the
 
Observation
Method in the applicable Final Terms, the relevant Interest Period; or
(2)
 
where
 
"Observation
 
Shift"
 
is
 
specified
 
as
 
the
 
Observation
 
Method
 
in
the applicable Final Terms, the relevant Observation Period;
d
o
is the number of
 
U.S. Government Securities
 
Business Days in:
(1)
 
where
 
"Lookback"
 
or
 
“Lock-out”
 
is
 
specified
 
as
 
the
 
Observation
Method in the applicable Final Terms, the relevant Interest Period; or
(2)
 
where
 
"Observation
 
Shift"
 
is
 
specified
 
as
 
the
 
Observation
 
Method
 
in
the applicable Final Terms, the relevant Observation Period;
i
is a series
 
of whole numbers from
 
one to d
o
, each representing
 
the relevant
U.S.
 
Government
 
Securities
 
Business
 
Day
 
in
 
chronological
 
order
 
from,
 
and
including, the first U.S. Government Securities Business Day in:
(1)
 
where
 
"Lookback"
 
or
 
“Lock-out”
 
is
 
specified
 
as
 
the
 
Observation
Method in the applicable Final Terms, the relevant Interest Period; or
(2)
 
where
 
"Observation
 
Shift"
 
is
 
specified
 
as
 
the
 
Observation
 
Method
 
in
the applicable Final Terms, the relevant Observation Period;
Lock-out Period
means the period
 
from (and including)
 
the day following
 
the
Interest
 
Determination
 
Date
 
to
 
(but
 
excluding)
 
the
 
corresponding
 
Interest
Payment Date;
n
i
,
 
for any
 
U.S. Government
 
Securities Business
 
Day "i",
 
means the
 
number
of
 
calendar
 
days
 
from
 
(and
 
including)
 
such
 
U.S.
 
Government
 
Securities
Business
 
Day
 
"i"
 
up
 
to
 
(but
 
excluding)
 
the
 
following
 
U.S.
 
Government
Securities Business Day;
Observation Period
means, in
 
respect of
 
an Interest
 
Period, the
 
period from
(and including) the date falling "p" U.S. Government
 
Securities Business Days
prior to
 
the first
 
day of
 
such Interest
 
Period to
 
(but excluding)
 
the date
 
falling
"p"
 
U.S.
 
Government
 
Securities
 
Business
 
Days
 
prior
 
to
 
(1)
 
the
 
Interest
Payment
 
Date
 
for
 
such
 
Interest
 
Period
 
or
 
(2)
 
such
 
earlier
 
date,
 
if
 
any,
 
on
which the Notes become due and payable;
p
means:
(1)
 
where
 
"Lookback"
 
is
 
specified
 
as
 
the
 
Observation
 
Method
 
in
 
the
applicable
 
Final
 
Terms,
 
the
 
number
 
of
 
U.S.
 
Government
 
Securities
Business
 
Days
 
specified
 
as
 
the
 
"Lookback
 
Period
 
(
p
)"
 
in
 
the
applicable Final Terms (or,
 
if no such number is so specified, five U.S.
Government Securities
 
Business Days); or
(2)
 
where
 
“Lock-out”
 
is
 
specified
 
as
 
the
 
Observation
 
Method
 
in
 
the
applicable
 
Final
 
Terms,
 
zero
 
U.S.
 
Government
 
Securities
 
Business
Days; or
(3)
 
where
 
"Observation
 
Shift"
 
is
 
specified
 
as
 
the
 
Observation
 
Method
 
in
the applicable Final Terms, the number of U.S. Government Securities
0010155-0003327 UKO2:
 
2004375908.9
58
Business
 
Days
 
specified
 
as
 
the
 
"Observation
 
Shift
 
Period"
 
in
 
the
applicable Final Terms
 
(or, if
 
no such number is so specified,
 
five U.S.
Government Securities Business Days);
Reference Day
means each U.S. Government Securities Business Day in the
relevant Interest Period, other
 
than any U.S. Government
 
Securities Business
Day in the Lock-out Period;
SOFR
means, in respect
 
of any U.S.
 
Government Securities Business Day,
 
a
rate determined in accordance with the following provisions:
(1)
 
the
 
Secured
 
Overnight
 
Financing
 
Rate
 
published
 
for
 
such
 
U.S.
Government
 
Securities
 
Business
 
Day
 
that
 
appears
 
on
 
the
 
SOFR
Administrator's Website at
 
or about 3.00
 
p.m. (New York
 
City time) on
the
 
U.S.
 
Government
 
Securities
 
Business
 
Day
 
immediately
 
following
such U.S. Government Securities Business Day; and
(2)
 
if the rate specified in paragraph (1) above does not so appear,
 
unless
both
 
a
 
Benchmark
 
Transition
 
Event
 
and
 
its
 
related
 
Benchmark
Replacement
 
Date
 
have
 
occurred,
 
then
 
the
 
Agent
 
or
 
the
 
Calculation
Agent, as
 
applicable, shall use
 
the Secured Overnight
 
Financing Rate
published on the SOFR Administrator's Website for the first preceding
U.S.
 
Government
 
Securities
 
Business
 
Day
 
on
 
which
 
the
 
Secured
Overnight Financing Rate was
 
published on the SOFR
 
Administrator's
Website;
SOFR
i
means,
 
in
 
respect
 
of
 
any
 
U.S.
 
Government
 
Securities
 
Business
 
Day
"i":
(1)
 
where
 
"Lookback"
 
is
 
specified
 
as
 
the
 
Observation
 
Method
 
in
 
the
applicable
 
Final
 
Terms,
 
SOFR
 
in
 
respect
 
of
 
the
 
U.S.
 
Government
Securities
 
Business
 
Day
 
falling
 
"
p
"
 
U.S.
 
Government
 
Securities
Business
 
Days
 
prior
 
to
 
the
 
relevant
 
U.S.
 
Government
 
Securities
Business Day "i"; or
(2)
 
where
 
“Lock-out”
 
is
 
specified
 
as
 
the
 
Observation
 
Method
 
in
 
the
applicable Final Terms:
(I)
 
in
 
respect
 
of
 
each
 
U.S.
 
Government
 
Securities
 
Business
 
Day
“i”
 
that
 
is
 
a
 
Reference
 
Day,
 
SOFR
 
in
 
respect
 
of
 
the
 
U.S.
Government
 
Securities
 
Business
 
Day
 
immediately
 
preceding
such Reference Day; or
(II)
 
in
 
respect
 
of
 
each
 
U.S.
 
Government
 
Securities
 
Business
 
Day
“i”
 
that
 
is
 
not
 
a
 
Reference
 
Day
 
(being
 
a
 
U.S.
 
Government
Securities
 
Business
 
Day
 
in
 
the
 
Lock-out
 
Period),
 
SOFR
 
in
respect
 
of
 
the
 
U.S.
 
Government
 
Securities
 
Business
 
Day
immediately
 
preceding
 
the
 
last
 
Reference
 
Day of
 
the
 
relevant
Interest
 
Period
 
(such
 
last
 
Reference
 
Day
 
coinciding
 
with
 
the
Interest Determination Date); or
(3)
 
where
 
"Observation
 
Shift"
 
is
 
specified
 
as
 
the
 
Observation
 
Method
 
in
the applicable Final Terms,
 
SOFR in respect of such U.S. Government
Securities Business Day "i"; and
exhibit25p60i0
0010155-0003327 UKO2:
 
2004375908.9
59
U.S.
 
Government
 
Securities
 
Business
 
Day
means
 
any
 
day
 
except
 
for
 
a
Saturday,
 
a
 
Sunday
 
or
 
a
 
day
 
on
 
which
 
the
 
Securities
 
Industry
 
and
 
Financial
Markets
 
Association
 
recommends
 
that
 
the
 
fixed
 
income
 
departments
 
of
 
its
members
 
be
 
closed
 
for
 
the
 
entire
 
day
 
for
 
purposes
 
of
 
trading
 
in
 
U.S.
government securities.
Certain
 
other
 
capitalised
 
terms
 
used
 
in
 
the
 
foregoing
 
terms
 
and
 
provisions
relating to
 
determination of the
 
Compounded Daily SOFR
 
Formula Rate have
the meanings set
 
forth under Condition
 
(
Benchmark Discontinuation –
SOFR
) below.
Notwithstanding anything
 
to
 
the
 
contrary,
 
if
 
both a
 
Benchmark Transition
 
Event and
its
 
related
 
Benchmark
 
Replacement
 
Date
 
have
 
occurred
 
with
 
respect
 
to
 
the
Compounded
 
Daily
 
SOFR
 
Formula
 
Rate
 
(or
 
any
 
component
 
part
 
thereof),
 
the
benchmark
 
replacement
 
provisions
 
set
 
forth
 
in
 
Condition
 
(
Benchmark
Discontinuation –
 
SOFR
)
 
below shall
 
apply for
 
the purposes
 
of all
 
determinations of
the Rate of Interest in respect of the Notes.
If
 
the
 
Notes
 
become
 
due
 
and
 
payable
 
in
 
accordance
 
with
 
Condition
 
8
 
(
Events
 
of
Default
),
 
the
 
final
 
Rate
 
of
 
Interest
 
shall
 
be
 
calculated
 
for
 
the
 
period
 
from
 
(and
including)
 
the
 
previous
 
Interest
 
Payment
 
Date
 
to
 
(but
 
excluding)
 
the
 
date
 
on
 
which
the
 
Notes
 
become so
 
due
 
and
 
payable,
 
and
 
such
 
Rate
 
of
 
Interest
 
shall
 
continue
 
to
apply to
 
the Notes
 
for so
 
long as
 
interest continues to
 
accrue thereon as
 
provided in
Condition
 
(
Accrual of Interest
).
(F)
Screen
 
Rate
 
Determination
 
for
 
Floating
 
Rate
 
Notes
 
–
 
Compounded
 
Daily
 
SOFR
 
–
Index Determination
Where the
 
applicable Final
 
Terms
 
specifies: (1)
 
“Screen Rate
 
Determination” as
 
the
manner in
 
which the
 
Rate of
 
Interest is
 
to be
 
determined and
 
“Overnight Rate”
 
to be
“Applicable”;
 
(2)
 
“Compounded Daily
 
SOFR”
 
as
 
the
 
Reference
 
Rate;
 
and
 
(3)
 
“Index
Determination”
 
to
 
be
 
“Applicable”,
 
the
 
Rate
 
of
 
Interest
 
for
 
an
 
Interest
 
Period
 
will,
subject
 
to
 
Condition
 
3(b)(ix)
 
(
Benchmark
 
Discontinuation
 
–
 
SOFR
)
 
and
 
as
 
provided
below,
 
be
 
the
 
Compounded
 
Daily
 
SOFR
 
Index
 
Rate
 
with
 
respect
 
to
 
such
 
Interest
Period
 
plus
 
or
 
minus
 
(as
 
indicated
 
in
 
the
 
applicable
 
Final
 
Terms)
 
the
 
applicable
Margin (if any).
Compounded SOFR
 
Index Rate
means, with respect to
 
an Interest Period,
 
the rate
of
 
return
 
of
 
a
 
daily compound
 
interest
 
investment as
 
calculated by
 
the
 
Agent
 
or
 
the
Calculation
 
Agent,
 
as
 
applicable,
 
on
 
the
 
relevant
 
Interest
 
Determination
 
Date
 
in
accordance with
 
the following formula
 
(and the
 
resulting percentage
 
will be
 
rounded,
if
 
necessary,
 
to
 
the
 
nearest
 
fifth
 
decimal
 
place,
 
with
 
0.000005
 
being
 
rounded
upwards):
where:
d
is
 
the
 
number
 
of
 
calendar
 
days
 
from
 
(and
 
including)
 
the
 
day
 
in
 
relation
 
to
which "SOFR
 
Index
Start
" is
 
determined to
 
(but excluding)
 
the day
 
in relation
 
to
which "SOFR Index
End
" is determined;
0010155-0003327 UKO2:
 
2004375908.9
60
Relevant
 
Number
is
 
the
 
number
 
specified
 
as
 
such
 
in
 
the
 
applicable
 
Final
Terms
 
(or, if no such number is specified, five);
SOFR Index
End
means the SOFR Index value relating to the U.S. Government
Securities
 
Business
 
Day
 
falling
 
the
 
Relevant
 
Number
 
of
 
U.S.
 
Government
Securities
 
Business
 
Days
 
prior
 
to
 
(1)
 
the
 
Interest
 
Payment
 
Date
 
for
 
the
relevant
 
Interest
 
Period
 
or
 
(2)
 
such
 
earlier
 
date,
 
if
 
any,
 
on
 
which
 
the
 
Notes
become due and payable;
SOFR
 
Index
Start
means
 
the
 
SOFR
 
Index
 
value
 
relating
 
to
 
the
 
U.S.
Government
 
Securities
 
Business
 
Day
 
falling
 
the
 
Relevant
 
Number
 
of
 
U.S.
Government
 
Securities
 
Business
 
Days
 
prior
 
to
 
the
 
first
 
date
 
of
 
the
 
relevant
Interest Period;
the
SOFR
 
Index
means,
 
with
 
respect
 
to
 
any
 
U.S.
 
Government
 
Securities
Business
 
Day,
 
prior
 
to
 
a
 
Benchmark
 
Replacement
 
Date,
 
the
 
SOFR
 
Index
published
 
for
 
such
 
U.S.
 
Government
 
Securities Business
 
Day
 
as
 
such
 
value
appears
 
on
 
the
 
SOFR
 
Administrator's
 
Website
 
at
 
3:00
 
p.m.
 
(New
 
York
 
City
time) on such U.S. Government Securities Business Day; and
U.S.
 
Government
 
Securities
 
Business
 
Day
has
 
the
 
meaning
 
set
 
out
 
in
Condition
 
above.
Certain
 
other
 
capitalised
 
terms
 
used
 
in
 
the
 
foregoing
 
terms
 
and
 
provisions
relating
 
to
 
determination
 
of
 
the
 
Compounded
 
SOFR
 
Index
 
Rate
 
have
 
the
meanings
 
set
 
forth
 
under
 
Condition
 
(
Benchmark
 
Discontinuation
 
–
SOFR
) below.
If, where any Rate
 
of Interest is to
 
be calculated pursuant to this
 
Condition
,
the
 
Agent
 
or
 
the
 
Calculation
 
Agent,
 
as
 
applicable,
 
determines
 
that
 
the
 
SOFR
Index
Start
or
 
the
 
SOFR
 
Index
End
does
 
not
 
appear
 
on
 
the
 
SOFR
 
Administrator's
Website
 
by
 
3.00
 
p.m.
 
(New
 
York
 
City
 
time)
 
on
 
the
 
relevant
 
Interest
 
Determination
Date
 
and
 
a
 
Benchmark
 
Transition
 
Event
 
and
 
its
 
related
 
Benchmark
 
Replacement
Date
 
have not
 
occurred with
 
respect to
 
the
 
Compounded SOFR
 
Index
 
Rate (or
 
any
component
 
part
 
thereof),
 
the
 
Compounded
 
SOFR
 
Index
 
Rate
 
for
 
the
 
applicable
Interest
 
Period
 
for
 
which
 
such
 
SOFR
 
Index
 
value
 
is
 
not
 
available
 
shall
 
be
 
the
"Compounded
 
Daily
 
SOFR Formula
 
Rate"
 
determined in
 
accordance with
 
Condition
 
above
 
as
 
if
 
Index
 
Determination
 
had
 
been
 
specified
 
as
 
being
 
Not
Applicable
 
in
 
the
 
applicable
 
Final
 
Terms,
 
and
 
for
 
these
 
purposes:
 
(1)
 
the
"Observation
 
Method"
 
shall
 
be
 
deemed
 
to
 
be
 
"Observation
 
Shift",
 
and
 
(2)
 
the
"Observation
 
Shift
 
Period"
 
shall
 
be
 
deemed to
 
be
 
equal
 
to
 
the
 
Relevant Number
 
of
U.S.
 
Government
 
Securities
 
Business
 
Days,
 
as
 
if
 
those
 
alternative
 
elections
 
had
been made in the applicable Final Terms.
Notwithstanding anything
 
to
 
the
 
contrary,
 
if
 
both
 
a
 
Benchmark Transition
 
Event
 
and
its
 
related
 
Benchmark
 
Replacement
 
Date
 
have
 
occurred
 
with
 
respect
 
to
 
the
Compounded
 
SOFR
 
Index
 
Rate
 
(or
 
any
 
component
 
part
 
thereof),
 
the
 
benchmark
replacement
 
provisions
 
set
 
forth
 
in
 
Condition
 
(
Benchmark
 
Discontinuation
 
–
SOFR
) below shall apply for the purposes of
 
all determinations of the Rate of Interest
in respect of the Notes.
If
 
the
 
Notes
 
become
 
due
 
and
 
payable
 
in
 
accordance
 
with
 
Condition
 
8
 
(
Events
 
of
Default
),
 
the
 
final
 
Rate
 
of
 
Interest
 
shall
 
be
 
calculated
 
for
 
the
 
period
 
from
 
(and
including)
 
the
 
previous
 
Interest
 
Payment
 
Date
 
to
 
(but
 
excluding) the
 
date
 
on
 
which
exhibit25p62i0
0010155-0003327 UKO2:
 
2004375908.9
61
the
 
Notes
 
become so
 
due
 
and
 
payable,
 
and
 
such
 
Rate
 
of
 
Interest
 
shall
 
continue
 
to
apply to
 
the Notes
 
for so
 
long as
 
interest continues to
 
accrue thereon
 
as provided in
Condition
 
(
Accrual of Interest
).
(G)
Screen Rate Determination
 
for Floating Rate Notes
 
– Average SOFR
Where the
 
applicable Final
 
Terms
 
specifies: (1)
 
“Screen Rate
 
Determination” as
 
the
manner in
 
which the
 
Rate of
 
Interest is
 
to be
 
determined and
 
“Overnight Rate”
 
to be
“Applicable”;
 
(2)
 
“Average
 
SOFR”
 
as
 
the
 
Reference
 
Rate;
 
and
 
(3)
 
“Index
Determination” to
 
be “Not
 
Applicable”, the Rate
 
of Interest
 
for an
 
Interest Period
 
will,
subject
 
to
 
Condition
 
3(b)(ix)
 
(
Benchmark
 
Discontinuation
 
–
 
SOFR
)
 
and
 
as
 
provided
below, be
 
the Average SOFR Rate with
 
respect to such Interest Period
 
plus or minus
(as indicated in the applicable Final Terms) the applicable Margin (if any).
Average
 
SOFR Rate
means, with respect
 
to an Interest
 
Period, the arithmetic
 
mean
of
 
SOFR
 
in
 
effect
 
during
 
such
 
Interest
 
Period
 
as
 
calculated
 
by
 
the
 
Agent
 
or
 
the
Calculation
 
Agent,
 
as
 
applicable,
 
on
 
the
 
relevant
 
Interest
 
Determination
 
Date
 
in
accordance with
 
the following formula
 
(and the
 
resulting percentage will
 
be rounded,
if
 
necessary,
 
to
 
the
 
nearest
 
fifth
 
decimal
 
place,
 
with
 
0.000005
 
being
 
rounded
upwards):
where
d
o
,
i
,
SOFR
,
SOFR
i
,
n
i
and
d
have
 
the
 
meanings
 
set
 
out
 
in
 
Condition
 
above.
Notwithstanding anything
 
to
 
the
 
contrary,
 
if
 
both a
 
Benchmark Transition
 
Event
 
and
its related
 
Benchmark Replacement Date
 
have occurred
 
with respect
 
to the
 
Average
SOFR Rate
 
(or any
 
component part
 
thereof), the
 
benchmark replacement
 
provisions
set forth in
 
Condition
 
(
Benchmark Discontinuation – SOFR
) below shall apply
for the purposes of all determinations of the Rate of Interest in
 
respect of the Notes.
If
 
the
 
Notes
 
become
 
due
 
and
 
payable
 
in
 
accordance
 
with
 
Condition
 
8
 
(
Events
 
of
Default
),
 
the
 
final
 
Rate
 
of
 
Interest
 
shall
 
be
 
calculated
 
for
 
the
 
period
 
from
 
(and
including)
 
the
 
previous
 
Interest
 
Payment
 
Date
 
to
 
(but
 
excluding)
 
the
 
date
 
on
 
which
the
 
Notes
 
become so
 
due
 
and
 
payable,
 
and
 
such
 
Rate
 
of
 
Interest
 
shall
 
continue
 
to
apply to
 
the Notes
 
for so
 
long as
 
interest continues to
 
accrue thereon as
 
provided in
Condition
 
(
Accrual of Interest
).
(iii)
Minimum and/or Maximum
 
Rate of Interest
If
 
the
 
applicable
 
Final
 
Terms
 
specifies
 
a
 
Minimum
 
Rate
 
of
 
Interest
 
for
 
any
 
Interest
Period, then,
 
in the
 
event that
 
the Rate
 
of Interest
 
in respect
 
of such
 
Interest Period
determined
 
in
 
accordance
 
with
 
the
 
provisions
 
of
 
paragraph
 
is
 
less
 
than
such Minimum
 
Rate of
 
Interest, the
 
Rate of
 
Interest for
 
such Interest
 
Period shall
 
be
such
 
Minimum
 
Rate
 
of
 
Interest.
 
If
 
the
 
applicable
 
Final
 
Terms
 
specifies
 
a
 
Maximum
Rate of
 
Interest for
 
any Interest
 
Period, then,
 
in the
 
event that
 
the Rate
 
of Interest
 
in
respect
 
of
 
such
 
Interest
 
Period
 
determined
 
in
 
accordance
 
with
 
the
 
provisions
 
of
paragraph
 
is
 
greater
 
than
 
such
 
Maximum
 
Rate
 
of
 
Interest,
 
the
 
Rate
 
of
Interest for such Interest Period shall be such Maximum Rate
 
of Interest.
(iv)
Determination of Rate
 
of Interest and
 
Calculation of Interest
 
Amounts
exhibit25p63i4 exhibit25p63i3 exhibit25p63i2 exhibit25p63i4 exhibit25p63i3 exhibit25p63i3 exhibit25p63i1 exhibit25p63i0
 
0010155-0003327 UKO2:
 
2004375908.9
62
The
 
Agent
 
or
 
the
 
Calculation Agent,
 
as
 
applicable, will
 
at
 
or
 
as
 
soon
 
as practicable
after each time
 
at which the
 
Rate of Interest
 
is to be
 
determined, determine the
 
Rate
of Interest for the relevant Interest Period.
The
 
Agent
 
or
 
the
 
Calculation
 
Agent,
 
as
 
applicable,
 
will
 
calculate
 
the
 
amount
 
of
interest
 
(the
Interest
 
Amount
)
 
payable
 
on
 
the
 
Floating
 
Rate
 
Notes
 
for
 
the
 
relevant
Interest Period by applying the Rate of Interest to:
(A)
 
in
 
the
 
case
 
of
 
Floating Rate
 
Notes
 
which
 
are
 
represented
 
by
 
a
 
Global
 
Note,
the aggregate
 
outstanding nominal amount
 
of the
 
Notes represented
 
by such
Global Note; or
(B)
 
in the case of
 
Floating Rate Notes in
 
definitive form, the
 
Calculation Amount;
and,
 
in
 
each
 
case,
 
multiplying such
 
sum
 
by the
 
applicable Day
 
Count
 
Fraction,
 
and
rounding
 
the
 
resultant
 
figure
 
to
 
the
 
nearest
 
sub-unit
 
of
 
the
 
relevant
 
Specified
Currency
 
half
 
of
 
any
 
such
 
sub-unit
 
being
 
rounded
 
upwards
 
or
 
otherwise
 
in
accordance with applicable market
 
convention. Where the Specified
 
Denomination of
a
 
Floating
 
Rate
 
Note
 
in
 
definitive
 
form
 
is
 
a
 
multiple
 
of
 
the
 
Calculation
 
Amount,
 
the
Interest Amount
 
payable in
 
respect of
 
such Note
 
shall be
 
the product
 
of the
 
amount
(determined
 
in
 
the
 
manner
 
provided
 
above)
 
for
 
the
 
Calculation
 
Amount
 
and
 
the
amount
 
by
 
which
 
the
 
Calculation
 
Amount
 
is
 
multiplied
 
to
 
reach
 
the
 
Specified
Denomination, without any further rounding.
Day Count
 
Fraction
means, in
 
respect of the
 
calculation of
 
an amount of
 
interest in
accordance with this Condition 3 (
Interest
):
(i)
 
if
 
"Actual/Actual (ISDA)"
 
or "Actual/Actual"
 
is specified
 
in the
 
applicable Final
Terms,
 
the actual
 
number of
 
days in
 
the Interest
 
Period divided
 
by 365
 
(or,
 
if
any portion of that Interest
 
Period falls in a
 
leap year, the
 
sum of (I) the
 
actual
number
 
of
 
days
 
in
 
that
 
portion
 
of
 
the
 
Interest
 
Period
 
falling
 
in
 
a
 
leap
 
year
divided by 366 and (II) the actual number of days in that
 
portion of the Interest
Period falling in a non-leap year divided by 365);
(ii)
 
if
 
"Actual/365
 
(Fixed)"
 
is
 
specified
 
in
 
the
 
applicable
 
Final
 
Terms,
 
the
 
actual
number of days in the Interest Period divided by 365;
(iii)
 
if
 
"Actual/365 (Sterling)"
 
is specified
 
in the
 
applicable Final
 
Terms,
 
the actual
number
 
of
 
days
 
in
 
the
 
Interest
 
Period
 
divided
 
by
 
365
 
or,
 
in
 
the
 
case
 
of
 
an
Interest Payment Date falling in a leap year, 366;
(iv)
 
if "Actual/360" is
 
specified in the
 
applicable Final Terms,
 
the actual number of
days in the Interest Period divided by 360;
(v)
 
if
 
"30/360",
 
"360/360"
 
or
 
"Bond
 
Basis"
 
is
 
specified
 
in
 
the
 
applicable
 
Final
Terms,
 
the number of days in the Interest Period divided by 360, calculated on
a formula basis as follows:
[360
(Y
2
 
Y
1
)]
[30
(M
2
M
1
)]
 
(D
2
D
1
)
DayCount
 
Fraction
where:
360
 
exhibit25p64i3 exhibit25p64i1 exhibit25p64i8 exhibit25p64i1 exhibit25p64i6 exhibit25p64i4 exhibit25p64i2 exhibit25p64i0 exhibit25p64i9 exhibit25p64i1 exhibit25p64i1 exhibit25p63i3 exhibit25p64i1 exhibit25p64i6 exhibit25p64i6 exhibit25p63i2
 
0010155-0003327 UKO2:
 
2004375908.9
63
"Y
1
" is
 
the year,
 
expressed as
 
a number,
 
in which
 
the first
 
day of
 
the Interest
Period falls:
"Y
2
"
 
is
 
the
 
year,
 
expressed
 
as
 
a
 
number,
 
in
 
which
 
the
 
day
 
immediately
following the last day of the Interest Period falls;
"M
1
" is
 
the calendar
 
month, expressed
 
as a
 
number,
 
in which
 
the first
 
day of
the Interest Period falls;
"M
2
"
 
is
 
the
 
calendar
 
month,
 
expressed
 
as
 
a
 
number,
 
in
 
which
 
the
 
day
immediately following the last day of the Interest Period falls;
"D
1
"
 
is the
 
first calendar
 
day,
 
expressed as
 
a number,
 
of the
 
Interest Period,
unless such number is 31, in which case D
1
will be 30; and
"D
2
"
 
is
 
the
 
calendar
 
day,
 
expressed
 
as
 
a
 
number,
 
immediately
 
following
 
the
last day
 
included in the
 
Interest Period, unless
 
such number would
 
be 31 and
D
1
is greater than 29, in which case D
2
will be 30;
(vi)
 
if
 
"30E/360"
 
or
 
"Eurobond
 
Basis"
 
is
 
specified
 
in
 
the
 
applicable
 
Final
 
Terms,
the
 
number
 
of
 
days
 
in
 
the
 
Interest
 
Period
 
divided
 
by
 
360,
 
calculated
 
on
 
a
formula basis as follows:
[360
(Y
2
 
Y
1
)]
[30
(M
2
M
1
)]
 
(D
2
D
1
)
DayCount
 
Fraction
where:
360
"Y
1
" is
 
the year,
 
expressed as
 
a number,
 
in which
 
the first
 
day of
 
the Interest
Period falls:
"Y
2
"
 
is
 
the
 
year,
 
expressed
 
as
 
a
 
number,
 
in
 
which
 
the
 
day
 
immediately
following the last day of the Interest Period falls;
"M
1
" is
 
the calendar
 
month, expressed
 
as a
 
number,
 
in which
 
the first
 
day of
the Interest Period falls;
"M
2
"
 
is
 
the
 
calendar
 
month,
 
expressed
 
as
 
a
 
number,
 
in
 
which
 
the
 
day
immediately following the last day of the Interest Period falls;
"D
1
"
 
is the
 
first calendar
 
day,
 
expressed as
 
a number,
 
of the
 
Interest Period,
unless such number would be 31, in which case D
1
will be 30; and
"D
2
"
 
is
 
the
 
calendar
 
day,
 
expressed
 
as
 
a
 
number,
 
immediately
 
following
 
the
last day
 
included in
 
the Interest
 
Period, unless
 
such number
 
would be
 
31, in
which case D
2
will be 30; or
(vii)
 
if
 
"30E/360 (ISDA)"
 
is specified
 
in
 
the
 
applicable Final
 
Terms,
 
the
 
number of
days
 
in
 
the
 
Interest
 
Period
 
divided
 
by
 
360,
 
calculated on
 
a
 
formula
 
basis
 
as
follows:
DayCount
 
Fraction
[360
(Y
2
 
Y
1
)]
[30
(M
2
M
1
)]
 
(D
2
D
1
)
360
0010155-0003327 UKO2:
 
2004375908.9
64
where:
"Y
1
" is
 
the year,
 
expressed as
 
a number,
 
in which
 
the first
 
day of
 
the Interest
Period falls:
"Y
2
"
 
is
 
the
 
year,
 
expressed
 
as
 
a
 
number,
 
in
 
which
 
the
 
day
 
immediately
following the last day of the Interest Period falls;
"M
1
" is
 
the calendar
 
month, expressed
 
as a
 
number,
 
in which
 
the first
 
day of
the Interest Period falls;
"M
2
"
 
is
 
the
 
calendar
 
month,
 
expressed
 
as
 
a
 
number,
 
in
 
which
 
the
 
day
immediately following the last day of the Interest Period falls;
"D
1
"
 
is the
 
first calendar
 
day,
 
expressed as
 
a number,
 
of the
 
Interest Period,
unless (i) that day is
 
the last day of February or
 
(ii) such number would be 31,
in which case D1 will be 30; and
"D
2
"
 
is
 
the
 
calendar
 
day,
 
expressed
 
as
 
a
 
number,
 
immediately
 
following
 
the
last
 
day
 
included
 
in
 
the
 
Interest
 
Period,
 
unless
 
(i)
 
that
 
day
 
is
 
the
 
last
 
day
 
of
February but not the Maturity Date or (ii)
 
such number would be 31 and D
2
will
be 30.
(v)
Linear Interpolation
Where Linear
 
Interpolation is
 
specified as
 
applicable in
 
respect of
 
an Interest
 
Period
in
 
the
 
applicable
 
Final
 
Terms,
 
the
 
Rate
 
of
 
Interest
 
for
 
such
 
Interest
 
Period
 
shall
 
be
calculated by the Agent
 
or the Calculation Agent,
 
as applicable, by straight
 
line linear
interpolation by
 
reference to two
 
rates based
 
on the relevant
 
Reference Rate (where
Screen
 
Rate Determination
 
is
 
specified
 
as applicable
 
in
 
the
 
applicable Final
 
Terms)
or
 
the
 
relevant
 
Floating
 
Rate
 
Option
 
(where
 
ISDA
 
Determination
 
is
 
specified
 
as
applicable in
 
the applicable
 
Final Terms),
 
one of
 
which shall
 
be determined
 
as if
 
the
Designated Maturity were the period of time for
 
which rates are available next shorter
than
 
the
 
length
 
of
 
the
 
relevant
 
Interest
 
Period
 
and
 
the
 
other
 
of
 
which
 
shall
 
be
determined as
 
if the
 
Designated Maturity
 
were the
 
period of
 
time for
 
which rates
 
are
available next longer than the length of
 
the relevant Interest Period provided however
that if
 
there is
 
no rate
 
available for
 
a period
 
of time
 
next shorter
 
or,
 
as the
 
case may
be,
 
next
 
longer,
 
then
 
the
 
Agent
 
or
 
the
 
Calculation
 
Agent,
 
as
 
applicable,
 
shall
determine
 
such
 
rate
 
at
 
such
 
time
 
and
 
by
 
reference
 
to
 
such
 
sources
 
as
 
an
independent
 
adviser,
 
appointed
 
by
 
the
 
Issuer
 
and
 
acting
 
in
 
good
 
faith
 
and
 
in
 
a
commercially reasonable manner as an expert, determines appropriate.
Designated Maturity
means, in relation
 
to Screen Rate
 
Determination, the period
 
of
time designated in the Reference Rate.
(vi)
Notification of Rate
 
of Interest and
 
Interest Amounts
(A)
 
Except where “Screen
 
Rate Determination” is specified
 
in the applicable
 
Final
Terms
 
as
 
the
 
manner
 
in
 
which
 
the
 
Rate
 
of
 
Interest
 
is
 
to
 
be
 
determined and
“Overnight Rate”
 
is specified in
 
the applicable
 
Final Terms
 
to be
 
“Applicable”,
the
 
Agent
 
or
 
the
 
Calculation
 
Agent,
 
as
 
applicable,
 
will
 
cause
 
the
 
Rate
 
of
Interest
 
and
 
each
 
Interest
 
Amount
 
for
 
each
 
Interest
 
Period
 
and
 
the
 
relevant
Interest Payment Date to
 
be notified to
 
the Issuer and any
 
stock exchange on
which the relevant Floating Rate Notes are for the time being listed
 
and notice
0010155-0003327 UKO2:
 
2004375908.9
65
thereof to
 
be published in
 
accordance with Condition
 
(
Notices
) as
 
soon as
possible after
 
their determination
 
but in
 
no event
 
later than
 
the fourth
 
London
Business Day thereafter.
 
Each Interest Amount and Interest
 
Payment Date so
notified
 
may
 
subsequently
 
be
 
amended
 
(or
 
appropriate
 
alternative
arrangements made by way
 
of adjustment) without
 
prior notice in the
 
event of
an extension or shortening of the Interest Period. Any such amendment will be
promptly notified to
 
each stock
 
exchange on which
 
the relevant
 
Floating Rate
Notes are
 
for the
 
time being
 
listed and
 
to the
 
Noteholders in
 
accordance with
Condition
 
(
Notices
).
 
For
 
the
 
purposes
 
of
 
this
 
paragraph,
 
the
 
expression
London Business
 
Day
means a day (other
 
than a Saturday or
 
a Sunday) on
which banks
 
and foreign
 
exchange markets
 
are open
 
for general
 
business in
London.
(B)
 
Where “Screen Rate
 
Determination” is specified
 
in the applicable
 
Final Terms
as
 
the
 
manner
 
in
 
which
 
the
 
Rate
 
of
 
Interest
 
is
 
to
 
be
 
determined
 
and
“Overnight Rate”
 
is specified
 
in the
 
applicable Final Terms
 
to be
 
“Applicable”,
the
 
Agent
 
or
 
the
 
Calculation
 
Agent,
 
as
 
applicable,
 
will
 
cause
 
the
 
Rate
 
of
Interest
 
and
 
each
 
Interest
 
Amount
 
for
 
each
 
Interest
 
Period
 
and
 
the
 
relevant
Interest Payment Date to
 
be notified to
 
the Issuer and
 
any stock exchange on
which the relevant Floating Rate Notes are for the
 
time being listed and notice
thereof to
 
be published in
 
accordance with Condition
 
12 (
Notices
) as
 
soon as
possible
 
after
 
their
 
determination
 
but
 
in
 
no
 
event
 
later
 
than
 
(1)
 
where
 
the
applicable
 
Final
 
Terms
 
specifies
 
the
 
Reference Rate
 
as
 
“Compounded
 
Daily
SONIA”,
 
the
 
second
 
London
 
Banking
 
Day
 
thereafter
 
or
 
(2)
 
where
 
the
applicable
 
Final
 
Terms
 
specifies
 
the
 
Reference Rate
 
as
 
“Compounded
 
Daily
SOFR” or “Average SOFR”, the
 
second U.S. Government Securities Business
Day
 
thereafter.
 
Each Rate
 
of Interest,
 
Interest
 
Amount and
 
Interest
 
Payment
Date
 
so
 
notified
 
may
 
subsequently
 
be
 
amended
 
(or
 
appropriate
 
alternative
arrangements made by way
 
of adjustment) without
 
prior notice in the
 
event of
an
 
extension
 
or
 
shortening
 
of
 
the
 
relevant
 
Interest
 
Period.
 
Any
 
such
amendment or alternative arrangements will promptly be notified to each stock
exchange
 
on
 
which
 
the
 
relevant
 
Floating
 
Rate
 
Notes
 
are
 
for
 
the
 
time
 
being
listed and to the Noteholders in accordance with Condition 12 (
Notices
).
(vii)
Certificates to be Final
All
 
certificates,
 
communications,
 
opinions,
 
determinations,
 
calculations,
 
quotations
and decisions given,
 
expressed, made or
 
obtained for the
 
purposes of the
 
provisions
of this Condition
 
(
Interest on Floating Rate
 
Notes
) by the
 
Agent, an Independent
Adviser
 
(as
 
defined
 
below)
 
or
 
the
 
Calculation
 
Agent,
 
as
 
applicable,
 
shall
 
(in
 
the
absence
 
of
 
wilful
 
default,
 
bad
 
faith
 
or
 
manifest
 
error)
 
be
 
binding
 
on
 
the
 
Issuer,
 
the
Issuer’s designee (as
 
defined below), the
 
Guarantor (in the
 
case of Notes
 
having the
benefit of
 
the Guarantee), the
 
Agent, the Calculation
 
Agent, the other
 
Paying Agents
and all Noteholders
 
and Couponholders and (in
 
the absence as
 
aforesaid) no liability
to
 
the Issuer,
 
the Issuer’s
 
designee, the
 
Guarantor (in
 
the
 
case of
 
Notes having
 
the
benefit of
 
the Guarantee),
 
the
 
Noteholders or
 
the
 
Couponholders shall
 
attach to
 
the
Agent, an Independent Adviser or
 
the Calculation Agent, as
 
applicable, in connection
with the
 
exercise or
 
non-exercise by
 
it of
 
its powers,
 
duties and
 
discretions pursuant
to such provisions.
(viii)
Benchmark Discontinuation
Notwithstanding
 
the
 
foregoing
 
provisions
 
of
 
this
 
Condition
 
3(b)
 
(
Interest
 
on
 
Floating
Rate Notes
), if:
0010155-0003327 UKO2:
 
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66
(1)
 
the
 
Reference
 
Rate
 
specified
 
in
 
the
 
applicable
 
Final
 
Terms
 
is
 
neither
Compounded Daily SOFR nor Average SOFR; and
(2)
 
the
 
Issuer
 
determines
 
that
 
a
 
Benchmark
 
Event
 
(as
 
defined
 
below)
 
has
occurred
 
in
 
relation
 
to
 
a
 
Reference
 
Rate
 
at
 
any
 
time
 
when
 
any
 
Rate
 
of
Interest
 
(or
 
the
 
relevant
 
component
 
thereof)
 
remains
 
to
 
be
 
determined
 
by
reference to such Reference Rate,
then the following
 
provisions shall apply:
(A)
 
the Issuer shall use reasonable endeavours to appoint, as soon as reasonably
practicable, an
 
Independent Adviser
 
(as defined
 
below) to
 
determine (without
any
 
requirement
 
for
 
any
 
consent
 
or
 
approval
 
of
 
the
 
Noteholders
 
or
 
the
Couponholders),
 
no
 
later
 
than
 
10
 
days
 
prior
 
to
 
the
 
relevant
 
Interest
Determination
 
Date
 
relating
 
to
 
the
 
next
 
succeeding
 
Interest
 
Period
 
(the
IA
Determination
 
Cut-off
 
Date
),
 
a
 
Successor
 
Rate
 
(as
 
defined
 
below)
 
or,
alternatively,
 
if there is no
 
Successor Rate, an Alternative
 
Reference Rate (as
defined below),
 
and in
 
either case
 
an Adjustment
 
Spread (as
 
defined below),
for
 
the
 
purposes
 
of
 
determining
 
the
 
Rate
 
of
 
Interest
 
(or
 
the
 
relevant
component part thereof) applicable to the Notes;
(B)
 
if
 
a
 
Successor
 
Rate
 
or,
 
failing
 
which,
 
an
 
Alternative
 
Reference
 
Rate
 
(as
applicable)
 
is
 
determined
 
in
 
accordance
 
with
 
paragraph
 
(A)
 
above,
 
such
Successor
 
Rate
 
or,
 
failing
 
which,
 
such
 
Alternative
 
Reference
 
Rate
 
(as
applicable) shall be the Reference
 
Rate for each of the
 
future Interest Periods
for
 
which
 
the
 
Rate
 
of
 
Interest
 
(or
 
the
 
relevant
 
component
 
thereof)
 
was
otherwise
 
to
 
be
 
determined
 
by
 
reference
 
to
 
the
 
relevant
 
Reference
 
Rate
(subject to the subsequent operation of, and to
 
adjustment as provided in, this
Condition 3(b)(viii) (
Benchmark Discontinuation
));
(C)
 
if the
 
Independent Adviser
 
determines a
 
Successor Rate
 
or,
 
failing which,
 
an
Alternative
 
Reference
 
Rate
 
(as
 
applicable)
 
in
 
accordance
 
with
 
the
 
above
provisions,
 
the
 
Independent
 
Adviser,
 
following
 
consultation
 
with
 
the
 
Issuer,
may also specify
 
changes to these
 
Conditions, including but
 
not limited to
 
the
Day
 
Count
 
Fraction,
 
Relevant
 
Screen
 
Page,
 
Specified
 
Time,
 
Business
 
Day
Convention,
 
Business
 
Day,
 
Interest
 
Determination
 
Date,
 
Reference
 
Banks,
Additional Business Centre
 
and/or the definition
 
of Reference Rate
 
applicable
to the
 
Notes, and/or the
 
method for
 
determining the fallback
 
to the
 
Reference
Rate in relation to the Notes,
 
in each case in order to follow
 
market practice in
relation
 
to
 
the
 
Successor
 
Rate
 
or
 
the
 
Alternative
 
Reference
 
Rate
 
(as
applicable).
 
If
 
a
 
Successor
 
Rate
 
or
 
Alternative
 
Rate
 
is
 
determined
 
in
accordance
 
with
 
the
 
foregoing
 
provisions,
 
the
 
Independent
 
Adviser
 
(in
consultation
 
with
 
the
 
Issuer)
 
will
 
determine
 
the
 
Adjustment
 
Spread
 
to
 
be
applied to
 
such Successor
 
Rate or
 
Alternative Rate
 
(as the
 
case may
 
be) for
each
 
subsequent
 
determination
 
of
 
a
 
relevant
 
Rate
 
of
 
Interest
 
(or
 
a
 
relevant
component
 
part
 
thereof)
 
by
 
reference
 
to
 
such
 
Successor
 
Rate
 
or
 
Alternative
Rate (as
 
applicable). For
 
the avoidance
 
of doubt,
 
the Issuer
 
shall be
 
obliged,
and the
 
Issuer shall
 
direct the
 
Agent (if
 
applicable) who
 
(upon such
 
direction)
shall
 
be
 
obliged,
 
in
 
each
 
case
 
without
 
the
 
requirement
 
for
 
any
 
consent
 
or
approval
 
of
 
the
 
Noteholders
 
or
 
the
 
Couponholders,
 
to
 
use
 
its
 
reasonable
endeavours to
 
effect
 
such amendments
 
to
 
the Agency
 
Agreement and
 
these
Conditions,
 
as
 
applicable,
 
as
 
may
 
be
 
specified
 
by
 
the
 
Independent
 
Adviser
following
 
consultation
 
with
 
the
 
Issuer
 
in
 
order
 
to
 
give
 
effect
 
to
 
this
 
Condition
3(b)(viii)(C)
 
(such
 
amendments,
 
the
Benchmark
 
Amendments
).
 
For
 
the
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avoidance of doubt, no Noteholder or Couponholder consent shall be
 
required
in
 
connection
 
with
 
effecting
 
the
 
Benchmark
 
Amendments
 
or
 
such
 
other
changes, including for
 
the execution of
 
any documents, amendments
 
or other
steps by
 
the Issuer,
 
the Guarantor
 
(in the
 
case of
 
Notes having
 
the benefit
 
of
the
 
Guarantee)
 
or
 
the
 
Agent
 
(if
 
required).
 
Notwithstanding
 
the
 
foregoing
provisions
 
of
 
this
 
Condition,
 
the
 
Agent
 
shall
 
not
 
be
 
required
 
to
 
agree
 
to
 
the
amendments
 
and
 
changes
 
referred
 
to
 
above
 
that
 
in
 
the
 
Agent’s
 
opinion,
acting reasonably and in good faith, imposes more onerous obligations upon it
or
 
exposes
 
it
 
to
 
additional
 
duties,
 
responsibilities
 
or
 
liability,
 
or
 
reduces
 
or
amends
 
the
 
protective
 
provisions
 
afforded
 
to
 
the
 
Agent
 
in
 
the
 
Agency
Agreement.
(D)
 
the
 
Issuer
 
shall
 
promptly,
 
following
 
the
 
determination of
 
any
 
Successor Rate
or
 
Alternative
 
Reference
 
Rate
 
(as
 
applicable),
 
the
 
applicable
 
Adjustment
Spread
 
and
 
the
 
specific
 
terms
 
of
 
any
 
Benchmark
 
Amendments
 
give
 
notice
thereof
 
to
 
the
 
Agent
 
and,
 
in
 
accordance
 
with
 
Condition
 
12
 
(
Notices
),
 
the
Noteholders and the Couponholders (which notice shall be irrevocable);
(E)
 
if
 
a
 
Successor
 
Rate
 
or
 
an
 
Alternative
 
Reference
 
Rate
 
or,
 
in
 
either
 
case,
 
the
applicable Adjustment
 
Spread, is
 
not
 
determined by
 
an
 
Independent
 
Adviser
in accordance with the above
 
provisions prior to the relevant
 
IA Determination
Cut-off
 
Date,
 
then
 
the
 
Rate
 
of
 
Interest
 
for
 
the
 
next
 
Interest
 
Period
 
shall
 
be
determined
 
by
 
reference
 
to
 
the
 
original
 
Reference
 
Rate
 
and
 
the
 
fallback
provisions
 
set
 
out
 
in
 
Condition
(B),
 
(C)
 
or
 
(D),
 
as
 
applicable;
 
for
 
the
avoidance
 
of
 
doubt,
 
in
 
such
 
circumstances
 
the
 
Rate
 
of
 
Interest
 
for
 
any
subsequent Interest
 
Periods shall
 
be
 
subject to
 
the
 
subsequent operation
 
of,
and
 
to
 
adjustment
 
as
 
provided
 
in,
 
this
 
Condition
 
3(b)(viii)
 
(
Benchmark
Discontinuation
); and
(F)
 
an
 
Independent
 
Adviser
 
appointed
 
pursuant
 
to
 
this
 
Condition
 
3(b)(viii)
(
Benchmark
 
Discontinuation
)
 
shall
 
act
 
in
 
good
 
faith
 
and
 
in
 
a
 
commercially
reasonable
 
manner
 
and
 
in
 
accordance
 
with
 
the
 
provisions
 
of
 
this
 
Condition
3(b)(viii)
 
(
Benchmark
 
Discontinuation
)
 
in
 
respect
 
of
 
any
 
determination
 
made
by it pursuant to this Condition 3(b)(viii) (
Benchmark Discontinuation
).
The
 
occurrence
 
of
 
a
 
Benchmark
 
Event
 
shall
 
be
 
determined
 
by
 
the
 
Issuer
 
and
promptly
 
notified
 
by
 
the
 
Issuer
 
to
 
the
 
Agent,
 
the
 
Calculation
 
Agent
 
and
 
the
 
Paying
Agents. For
 
the avoidance
 
of doubt,
 
none of
 
the Agent,
 
the Calculation
 
Agent or
 
the
Paying Agents shall have any responsibility for making such determination.
For the purposes
 
of this Condition 3(b)(viii)
 
(
Benchmark Discontinuation
):
Adjustment
 
Spread
means
 
the
 
spread
 
(which
 
may
 
be
 
positive,
 
negative
 
or
 
zero),
quantum or
 
formula or
 
methodology for
 
calculating a
 
spread, which
 
the Independent
Adviser
 
(in
 
consultation
 
with
 
the
 
Issuer)
 
determines
 
is
 
required
 
to
 
be
 
applied
 
to
 
the
Successor Rate
 
or the
 
Alternative Reference
 
Rate (as
 
applicable) and
 
is the
 
spread,
quantum, formula or methodology which:
(1)
 
in
 
the
 
case
 
of
 
a
 
Successor
 
Rate,
 
is
 
formally
 
recommended
 
in
 
relation
 
to
 
the
replacement
 
of
 
the
 
Reference
 
Rate
 
with
 
the
 
Successor
 
Rate
 
by
 
any
 
Relevant
Nominating Body (as defined below); or
(2)
 
in the
 
case of
 
a Successor
 
Rate for
 
which no
 
such recommendation
 
as referred
to in (1) above has been made, or in the case of an Alternative Reference
 
Rate,
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the
 
Independent
 
Adviser
 
(in
 
consultation
 
with
 
the
 
Issuer)
 
determines
 
is
recognised or acknowledged as being in customary market usage in international
debt
 
capital
 
markets
 
transactions
 
which
 
reference
 
the
 
Reference
 
Rate,
 
where
such rate has been replaced by the
 
Successor Rate or the Alternative Reference
Rate (as applicable); or
(3)
 
if the
 
Independent Adviser determines
 
that neither
 
(1) nor
 
(2) above
 
applies, the
Independent Adviser (in
 
consultation with the
 
Issuer) in
 
its discretion determines
(acting
 
in
 
good
 
faith
 
and
 
in
 
a
 
commercially
 
reasonable
 
manner)
 
to
 
be
appropriate;
Alternative
 
Reference
 
Rate
means
 
the
 
rate
 
that
 
the
 
Independent
 
Adviser
 
(in
consultation
 
with
 
the
 
Issuer)
 
determines
 
(acting
 
in
 
good
 
faith
 
and
 
in
 
a
 
commercially
reasonable manner)
 
has replaced
 
the relevant
 
Reference Rate
 
in customary
 
market
usage
 
in
 
the
 
international
 
debt
 
capital
 
markets
 
for
 
the
 
purposes
 
of
 
determining
floating
 
rates
 
of
 
interest
 
(or
 
the
 
relevant
 
component
 
thereof)
 
in
 
respect
 
of
 
bonds
denominated
 
in the
 
Specified Currency
 
and with
 
an
 
interest period
 
of
 
a comparable
duration to the relevant Interest Period, or,
 
if the Independent Adviser (in consultation
with
 
the
 
Issuer)
 
determines
 
that
 
there
 
is
 
no
 
such
 
rate,
 
such
 
other
 
rate
 
as
 
the
Independent Adviser (in consultation
 
with the Issuer) determines
 
in its sole discretion
is most comparable to the relevant Reference Rate;
Benchmark Event
means, with respect
 
to a Reference
 
Rate:
(1)
 
the
 
Reference
 
Rate
 
(A)
 
ceasing
 
to
 
be
 
published
 
for
 
a
 
period
 
of
 
at
 
least
 
five
consecutive Business Days or (B) ceasing to exist or be administered;
 
or
(2)
 
the
 
later
 
of
 
(A)
 
the
 
making
 
of
 
a
 
public
 
statement
 
by
 
the
 
administrator
 
of
 
such
Reference Rate
 
that it
 
will, on
 
or before
 
a specified
 
date, cease
 
publishing such
Reference
 
Rate
 
permanently
 
or
 
indefinitely
 
(in
 
circumstances
 
where
 
no
successor administrator has been appointed that will continue publication of such
Reference
 
Rate)
 
and
 
(B)
 
the
 
date
 
falling
 
six
 
months
 
prior
 
to
 
the
 
specified
 
date
referred to in (2)(A); or
(3)
 
the
 
making
 
of
 
a public
 
statement by
 
the
 
supervisor of
 
the
 
administrator of
 
such
Reference Rate
 
that such
 
Reference Rate
 
has been
 
permanently or
 
indefinitely
discontinued; or
(4)
 
the
 
later
 
of
 
(A)
 
the
 
making
 
of
 
a
 
public
 
statement
 
by
 
the
 
supervisor
 
of
 
the
administrator of such Reference Rate that such Reference Rate will, on or before
a
 
specified
 
date,
 
be
 
permanently
 
or
 
indefinitely
 
discontinued
 
and
 
(B)
 
the
 
date
falling six months prior to the specified date referred to in (4)(A); or
(5)
 
the
 
later
 
of
 
(A)
 
the
 
making
 
of
 
a
 
public
 
statement
 
by
 
the
 
supervisor
 
of
 
the
administrator
 
of
 
such
 
Reference
 
Rate
 
that
 
means
 
such
 
Reference
 
Rate
 
will
 
be
prohibited from being used or that its use will be subject to restrictions or adverse
consequences,
 
in
 
each
 
case
 
on
 
or
 
before
 
a
 
specified
 
date
 
and
 
(B)
 
the
 
date
falling six months prior to the specified date referred to in (5)(A); or
(6)
 
a public statement by the supervisor of
 
the administrator of such Reference Rate
that,
 
in
 
the
 
view
 
of
 
such
 
supervisor,
 
such
 
Reference
 
Rate
 
is
 
no
 
longer
representative of its underlying market; or
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(7)
 
the later
 
of (A)
 
a public
 
statement by
 
the supervisor
 
of the
 
administrator of
 
such
Reference Rate that, in the view of such supervisor, such Reference Rate will, as
of a
 
specified date,
 
no longer
 
be representative
 
of its
 
underlying market
 
and (B)
the date falling six months prior to the specified date referred
 
to in (7)(A); or
(8)
 
it
 
has,
 
or
 
will
 
prior
 
to
 
the
 
next
 
Interest
 
Determination Date
 
become
 
unlawful for
the
 
Issuer,
 
the
 
Agent,
 
the
 
Calculation
 
Agent,
 
any
 
other
 
party
 
specified
 
in
 
the
applicable Final
 
Terms
 
as
 
being
 
responsible for
 
calculating the
 
Rate of
 
Interest
or
 
any
 
Paying
 
Agent
 
to
 
calculate
 
any
 
payments
 
due
 
to
 
be
 
made
 
to
 
any
Noteholder or Couponholder using such Reference Rate;
Independent
 
Adviser
means
 
an
 
independent
 
financial
 
institution
 
of
 
international
repute
 
or
 
other
 
independent
 
financial
 
adviser
 
experienced
 
in
 
the
 
international
 
debt
capital markets,
 
in each
 
case appointed
 
by the
 
Issuer at
 
its own
 
expense. For
 
the
avoidance
 
of
 
doubt,
 
neither
 
the
 
Agent
 
nor
 
the
 
Calculation
 
Agent
 
shall
 
act
 
as
 
the
Independent Adviser unless it accepts such appointment
 
in writing;
Relevant Nominating Body
means, in respect
 
of a Reference Rate:
(1)
 
the
 
central
 
bank
 
for
 
the
 
currency
 
to
 
which
 
the
 
Reference
 
Rate
 
relates,
 
or
 
any
central
 
bank
 
or
 
other
 
supervisory
 
authority
 
which
 
is
 
responsible
 
for
 
supervising
the administrator of the Reference Rate; or
(2)
 
any
 
working
 
group
 
or
 
committee
 
sponsored
 
by,
 
chaired
 
or
 
co-chaired
 
by
 
or
constituted
 
at
 
the
 
request
 
of
 
(a)
 
the
 
central
 
bank
 
for
 
the
 
currency
 
to
 
which
 
the
Reference Rate relates, (b) any central bank or other supervisory authority which
is
 
responsible
 
for
 
supervising
 
the
 
administrator
 
of
 
the
 
Reference
 
Rate,
 
(c)
 
a
group of the aforementioned central banks or other supervisory authorities, or (d)
the Financial Stability Board or any part thereof; and
Successor
 
Rate
means the
 
rate
 
that
 
the
 
Independent Adviser
 
(in
 
consultation
 
with
the
 
Issuer)
 
determines
 
(acting
 
in
 
good
 
faith
 
and
 
in
 
a
 
commercially
 
reasonable
manner)
 
is
 
a
 
successor
 
to
 
or
 
replacement
 
of
 
the
 
Reference
 
Rate
 
which
 
is
 
formally
recommended by any Relevant Nominating Body.
(ix)
Benchmark Discontinuation –
 
SOFR
Notwithstanding the
 
foregoing
 
provisions
 
of
 
this Condition
 
3(b)
 
(
Interest on
 
Floating
Rate Notes
), if:
(1)
 
the
 
Reference
 
Rate
 
specified
 
in
 
the
 
applicable
 
Final
 
Terms
 
is
 
either
Compounded Daily SOFR or Average SOFR; and
(2)
 
any
 
Rate
 
of
 
Interest
 
(or
 
any
 
component
 
part
 
thereof)
 
remains
 
to
 
be
determined by reference to the Benchmark,
then the following
 
provisions shall apply:
(A)
Benchmark Replacement
If
 
the Issuer
 
or
 
its
 
designee determines
 
prior to
 
the
 
Reference Time
 
on the
 
relevant
Interest
 
Determination
 
Date
 
that
 
a
 
Benchmark
 
Transition
 
Event
 
and
 
its
 
related
Benchmark
 
Replacement
 
Date
 
have
 
occurred
 
with
 
respect
 
to
 
the
 
then-current
Benchmark, the Benchmark Replacement
 
will replace the
 
then-current Benchmark for
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all purposes relating to the Notes in respect of all determinations on such date and all
determinations on all subsequent dates (subject to any
 
subsequent application of this
Condition
 
with respect to such Benchmark Replacement).
In
 
the
 
event
 
that
 
the
 
Issuer
 
or
 
its
 
designee
 
is
 
unable
 
to,
 
or
 
does
 
not,
 
determine
 
a
Benchmark
 
Replacement,
 
or
 
a
 
Benchmark
 
Replacement
 
is
 
not
 
implemented
 
in
accordance with this Condition
, prior to 5:00 p.m. (New York
 
City time) on the
relevant
 
Interest
 
Determination
 
Date,
 
the
 
Rate
 
of
 
Interest
 
for
 
the
 
relevant
 
Interest
Period shall be:
(1)
 
that determined
 
as at
 
the last
 
preceding Interest
 
Determination Date
 
(though
substituting,
 
where
 
a
 
different
 
Margin,
 
Maximum
 
Rate
 
of
 
Interest
 
and/or
Minimum Rate
 
of Interest
 
is to
 
be applied to
 
the relevant Interest
 
Period from
that which applied to the
 
last preceding Interest Period, the Margin,
 
Maximum
Rate
 
of
 
Interest
 
and/or
 
Minimum
 
Rate
 
of
 
Interest
 
(as
 
the
 
case
 
may
 
be)
relating to the
 
relevant Interest Period, in
 
place of the
 
Margin, Maximum Rate
of Interest and/or Minimum Rate of
 
Interest (as applicable) relating to that
 
last
preceding Interest Period); or
(2)
 
if
 
there
 
is
 
no
 
such
 
preceding
 
Interest
 
Determination
 
Date,
 
the
 
initial
 
Rate
 
of
Interest which would have been applicable to such Series of Notes for the first
scheduled
 
Interest
 
Period
 
had
 
the
 
Notes
 
been
 
in
 
issue
 
for
 
a
 
period
 
equal
 
in
duration
 
to
 
the
 
first
 
scheduled Interest
 
Period
 
but
 
ending
 
on
 
(and
 
excluding)
the Interest Commencement Date (and applying the Margin and,
 
if applicable,
any Maximum Rate
 
of Interest and/or
 
Minimum Rate of
 
Interest, applicable to
the first scheduled Interest Period).
(B)
Benchmark Replacement
 
Conforming Changes
In connection with the implementation of a Benchmark Replacement, the Issuer or its
designee will
 
have the
 
right to
 
make Benchmark
 
Replacement Conforming
 
Changes
from time to time.
The Issuer
 
shall be
 
obliged, and
 
the Issuer
 
shall direct
 
the Agent
 
(if applicable)
 
who
(upon such
 
direction) shall
 
be obliged,
 
in each
 
case without
 
the requirement
 
for any
consent or
 
approval of
 
the Noteholders
 
or the
 
Couponholders, to
 
use its
 
reasonable
endeavours
 
to
 
effect
 
any
 
Benchmark Replacement
 
Conforming Changes
 
(including,
inter alia
, by the
 
execution of a supplemental
 
Agency Agreement). For the avoidance
of doubt, no Noteholder or Couponholder consent shall be required in connection with
effecting the
 
Benchmark Replacement
 
Conforming Changes
 
or such
 
other changes,
including
 
for
 
the
 
execution
 
of
 
any
 
documents,
 
amendments
 
or
 
other
 
steps
 
by
 
the
Issuer,
 
the
 
Guarantor
 
(in
 
the
 
case
 
of
 
Notes
 
having
 
the
 
benefit
 
of
 
the
 
Guarantee)
 
or
the Agent (if required).
Notwithstanding
 
the
 
foregoing
 
provisions
 
of
 
this
 
Condition,
 
the
 
Agent
 
shall
 
not
 
be
required
 
to
 
agree
 
to
 
the
 
amendments
 
and
 
changes
 
referred
 
to
 
above
 
that
 
in
 
the
Agent’s
 
opinion,
 
acting
 
reasonably
 
and
 
in
 
good
 
faith,
 
imposes
 
more
 
onerous
obligations
 
upon
 
it
 
or
 
exposes
 
it
 
to
 
additional
 
duties,
 
responsibilities
 
or
 
liability,
 
or
reduces
 
or
 
amends
 
the
 
protective
 
provisions
 
afforded
 
to
 
the
 
Agent
 
in
 
the
 
Agency
Agreement.
(C)
Decisions and Determinations
0010155-0003327 UKO2:
 
2004375908.9
71
Any
 
determination,
 
decision
 
or
 
election
 
that
 
may
 
be
 
made
 
by
 
the
 
Issuer
 
or
 
its
designee
 
pursuant
 
to
 
this
 
Condition
,
 
including
 
(without
 
limitation)
 
any
determination with respect to
 
a tenor,
 
rate or adjustment or
 
of the occurrence or
 
non-
occurrence of an event, circumstance or date and any
 
decision to take or refrain from
taking
 
any
 
action
 
or
 
any
 
selection,
 
will
 
be
 
conclusive
 
and
 
binding
 
absent
 
manifest
error,
 
may
 
be
 
made
 
in
 
the
 
Issuer's
 
or
 
its
 
designee's
 
sole
 
discretion
 
(as
 
applicable),
and,
 
notwithstanding
 
anything
 
to
 
the
 
contrary
 
in
 
these
 
Conditions,
 
shall
 
become
effective
 
without
 
any
 
requirement
 
for
 
the
 
consent
 
or
 
approval
 
of
 
Noteholders,
Couponholders
 
or
 
any
 
other
 
party.
 
Neither
 
the
 
Agent
 
nor
 
the
 
Calculation
 
Agent
 
(if
applicable) shall have any responsibility to make any such
 
determinations or exercise
discretion with respect to the foregoing.
In connection with any Benchmark Replacement Conforming Changes in
 
accordance
with this Condition
, if and for so long as the Notes are
 
admitted to trading and
listed on the
 
official list of
 
a stock exchange,
 
the Issuer shall
 
comply with the
 
rules of
that stock exchange.
The
 
Agent
 
and the
 
Calculation Agent
 
(if
 
applicable) shall
 
be
 
entitled to
 
conclusively
rely on
 
any determination
 
made by
 
the Issuer
 
or its
 
designee and,
 
in the
 
absence of
fraud,
 
negligence
 
or
 
wilful
 
default,
 
will
 
have
 
no
 
liability
 
for
 
actions
 
taken
 
at
 
the
direction of the Issuer or its designee.
(D)
Notice and Certification
Any Benchmark Replacement
 
Conforming Changes determined under
 
this Condition
 
shall be notified promptly
 
by the Issuer
 
to the Agent,
 
the Calculation Agent (if
applicable)
 
and,
 
in
 
accordance
 
with
 
Condition
 
12
 
(
Notices
),
 
the
 
Noteholders.
 
Such
notice
 
shall
 
be
 
irrevocable
 
and
 
shall
 
specify
 
the
 
effective
 
date
 
of
 
such
 
Benchmark
Replacement Conforming Changes.
(E)
Definitions
In this Condition
Benchmark
means,
 
initially,
 
SOFR
 
(provided
 
that
 
if
 
a
 
Benchmark
 
Transition
 
Event
and
 
its
 
related
 
Benchmark
 
Replacement
 
Date
 
have
 
occurred
 
with
 
respect
 
to
 
SOFR
(or
 
the
 
published
 
daily
 
SOFR
 
used
 
in
 
the
 
calculation
 
thereof)
 
or
 
any
 
Benchmark
which
 
has
 
replaced
 
it
 
in
 
accordance
 
with
 
this
 
Condition
,
 
then
 
the
 
term
"
Benchmark
" means the applicable Benchmark Replacement);
Benchmark Replacement
means the first alternative set forth in the order below that
can be
 
determined by
 
the Issuer
 
or its
 
designee as
 
of the
 
Benchmark Replacement
Date:
(1)
 
the
 
sum
 
of:
 
(I)
 
the
 
alternate
 
rate
 
of
 
interest
 
that
 
has
 
been
 
selected
 
or
recommended
 
by
 
the
 
Relevant
 
Governmental
 
Body
 
as
 
the
 
replacement
 
for
the
 
then-current
 
Benchmark
 
and
 
(II)
 
the
 
Benchmark
 
Replacement
Adjustment;
(2)
 
the
 
sum of:
 
(I) the
 
ISDA Fallback
 
Rate and
 
(II) the
 
Benchmark Replacement
Adjustment; or
(3)
 
the
 
sum
 
of:
 
(I)
 
the
 
alternate
 
rate
 
of
 
interest
 
that
 
has
 
been
 
selected
 
by
 
the
Issuer
 
or
 
its
 
designee
 
as
 
the
 
replacement
 
for
 
the
 
then-current
 
Benchmark
0010155-0003327 UKO2:
 
2004375908.9
72
giving
 
due
 
consideration
 
to
 
any
 
industry-accepted
 
rate
 
of
 
interest
 
as
 
a
replacement
 
for
 
the
 
then-current
 
Benchmark
 
for
 
U.S.
 
dollar
 
denominated
floating
 
rate
 
notes
 
at
 
such
 
time
 
and
 
(II)
 
the
 
Benchmark
 
Replacement
Adjustment;
Benchmark
 
Replacement
 
Adjustment
means
 
the
 
first
 
alternative
 
set
 
forth
 
in
 
the
order
 
below
 
that
 
can
 
be
 
determined
 
by
 
the
 
Issuer
 
or
 
its
 
designee
 
as
 
of
 
the
Benchmark Replacement Date:
(1)
 
the spread
 
adjustment, or
 
method for
 
calculating or
 
determining such
 
spread
adjustment, (which may be a positive or negative value or zero) that
 
has been
selected
 
or
 
recommended
 
by
 
the
 
Relevant
 
Governmental
 
Body
 
for
 
the
applicable Unadjusted Benchmark Replacement;
(2)
 
if
 
the
 
applicable
 
Unadjusted
 
Benchmark
 
Replacement
 
is
 
equivalent
 
to
 
the
ISDA Fallback Rate, then the ISDA Fallback Adjustment; or
(3)
 
the
 
spread
 
adjustment
 
(which
 
may
 
be
 
a
 
positive
 
or
 
negative
 
value
 
or
 
zero)
that has
 
been selected by
 
the Issuer
 
or its
 
designee giving due
 
consideration
to
 
any
 
industry-accepted
 
spread
 
adjustment,
 
or
 
method
 
for
 
calculating
 
or
determining such
 
spread adjustment,
 
for the
 
replacement of
 
the then-current
Benchmark with
 
the applicable Unadjusted
 
Benchmark Replacement for
 
U.S.
dollar denominated floating rate notes at such time;
Benchmark
 
Replacement
 
Conforming
 
Changes
means,
 
with
 
respect
 
to
 
any
Benchmark
 
Replacement,
 
any
 
technical,
 
administrative
 
or
 
operational
 
changes
(including
 
changes
 
to
 
the
 
definition
 
of
 
Interest
 
Period,
 
timing
 
and
 
frequency
 
of
determining rates and making
 
payments of interest, rounding
 
amounts or tenors, and
other
 
administrative
 
matters)
 
that
 
the
 
Issuer
 
or
 
its
 
designee
 
decides
 
may
 
be
appropriate
 
to
 
reflect
 
the
 
adoption
 
of
 
such
 
Benchmark
 
Replacement
 
in
 
a
 
manner
substantially consistent with
 
market practice
 
(or,
 
if the
 
Issuer or
 
its designee
 
decides
that adoption of any
 
portion of such market practice
 
is not administratively feasible
 
or
if
 
the
 
Issuer
 
or
 
its
 
designee
 
determines
 
that
 
no
 
market
 
practice
 
for
 
use
 
of
 
the
Benchmark Replacement
 
exists, in
 
such other
 
manner as
 
the Issuer
 
or its
 
designee
determines is reasonably necessary);
Benchmark
 
Replacement
 
Date
means the
 
earliest to
 
occur of
 
the following
 
events
with respect to
 
the then-current Benchmark
 
(including the daily
 
published component
used in the calculation thereof):
(1)
 
in the
 
case of
 
paragraph (1)
 
or (2)
 
of the
 
definition of
 
"Benchmark Transition
Event",
 
the
 
later
 
of
 
(1)
 
the
 
date
 
of
 
the
 
public
 
statement
 
or
 
publication
 
of
information referenced
 
therein and
 
(2) the
 
date on
 
which the
 
administrator of
the Benchmark
 
permanently or
 
indefinitely ceases
 
to provide
 
the Benchmark
(or such component); or
(2)
 
in the case of paragraph (3) of
 
the definition of "Benchmark Transition Event",
the
 
date
 
of
 
the
 
public
 
statement
 
or
 
publication
 
of
 
information
 
referenced
therein.
For
 
the
 
avoidance of
 
doubt,
 
if
 
the
 
event
 
giving rise
 
to
 
the
 
Benchmark
 
Replacement
Date occurs on the same day as, but earlier than, the Reference Time on the relevant
Interest
 
Determination
 
Date,
 
the
 
Benchmark
 
Replacement
 
Date
 
will
 
be
 
deemed
 
to
have occurred prior to the Reference Time for such determination;
0010155-0003327 UKO2:
 
2004375908.9
73
Benchmark Transition
 
Event
means the occurrence of one or
 
more of the following
events
 
with
 
respect
 
to
 
the
 
then-current
 
Benchmark
 
(including
 
the
 
daily
 
published
component used in the calculation thereof):
(1)
 
a
 
public
 
statement
 
or
 
publication
 
of
 
information
 
by
 
or
 
on
 
behalf
 
of
 
the
administrator
 
of
 
the
 
Benchmark
 
(or
 
such
 
component)
 
announcing
 
that
 
such
administrator
 
has
 
ceased
 
or
 
will
 
cease
 
to
 
provide
 
the
 
Benchmark
 
(or
 
such
component),
 
permanently
 
or
 
indefinitely,
 
provided
 
that,
 
at
 
the
 
time
 
of
 
such
statement or publication, there is no successor administrator that
 
will continue
to provide the Benchmark (or such component);
(2)
 
a
 
public
 
statement
 
or
 
publication
 
of
 
information
 
by
 
the
 
regulatory
 
supervisor
for the administrator of
 
the Benchmark (or such
 
component), the central bank
for the currency of the
 
Benchmark (or such component), an insolvency official
with
 
jurisdiction
 
over
 
the
 
administrator
 
for
 
the
 
Benchmark
 
(or
 
such
component),
 
a
 
resolution
 
authority
 
with
 
jurisdiction
 
over
 
the
 
administrator for
the
 
Benchmark
 
(or
 
such
 
component)
 
or
 
a
 
court
 
or
 
an
 
entity
 
with
 
similar
insolvency or resolution authority over the administrator for the Benchmark (or
such
 
component),
 
which
 
states
 
that
 
the
 
administrator
 
of
 
the
 
Benchmark
 
(or
such component) has ceased or will cease to provide the Benchmark (or such
component)
 
permanently
 
or
 
indefinitely,
 
provided
 
that,
 
at
 
the
 
time
 
of
 
such
statement or publication, there is no successor administrator that will continue
to provide the Benchmark (or such component); or
(3)
 
a
 
public
 
statement
 
or
 
publication
 
of
 
information
 
by
 
the
 
regulatory
 
supervisor
for the
 
administrator of
 
the Benchmark
 
announcing that
 
the Benchmark
 
is no
longer representative;
designee
means an affiliate or any
 
other agent of the
 
Issuer;
ISDA
 
Definitions
means
 
the
 
2006
 
ISDA
 
Definitions
 
published
 
by
 
ISDA
 
or
 
any
successor thereto, as amended or
 
supplemented from time to time,
 
or any successor
definitional booklet for interest rate derivatives published
 
from time to time;
ISDA
 
Fallback Adjustment
means the
 
spread adjustment (which
 
may be
 
a positive
or
 
negative
 
value
 
or
 
zero)
 
that
 
would
 
apply
 
for
 
derivatives
 
transactions
 
referencing
the
 
ISDA
 
Definitions
 
to
 
be
 
determined
 
upon
 
the
 
occurrence
 
of
 
an
 
index
 
cessation
event with respect to the Benchmark;
ISDA
 
Fallback
 
Rate
means
 
the
 
rate
 
that
 
would
 
apply
 
for
 
derivatives
 
transactions
referencing
 
the
 
ISDA
 
Definitions
 
to
 
be
 
effective
 
upon
 
the
 
occurrence
 
of
 
an
 
index
cessation date
 
with respect
 
to
 
the Benchmark
 
for the
 
applicable tenor
 
excluding the
applicable ISDA Fallback Adjustment;
Reference Time
with respect to any determination of the Benchmark means (1) if the
Benchmark
 
is
 
SOFR,
 
3:00
 
p.m.
 
(New
 
York
 
City
 
time)
 
or
 
such
 
other
 
time
 
as
 
is
reasonably
 
agreed
 
between
 
the
 
Issuer
 
or
 
its
 
designee
 
and
 
the
 
Agent
 
or
 
the
Calculation
 
Agent,
 
as
 
applicable
 
and
 
(2)
 
if
 
the
 
Benchmark
 
is
 
not
 
SOFR,
 
the
 
time
determined
 
by
 
the
 
Issuer
 
or
 
its
 
designee
 
in
 
accordance
 
with
 
the
 
Benchmark
Replacement Conforming Changes;
Relevant
 
Governmental
 
Body
means
 
the
 
Federal
 
Reserve
 
Board
 
and/or
 
the
Federal Reserve Bank of New York, or a committee officially endorsed or convened
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74
by the
 
Federal Reserve Board
 
and/or the Federal
 
Reserve Bank of
 
New York
 
or any
successor thereto;
SOFR
with
 
respect
 
to
 
any
 
day
 
means
 
the
 
Secured
 
Overnight
 
Financing
 
Rate
published
 
for
 
such
 
day
 
by
 
the
 
SOFR
 
Administrator
 
on
 
the
 
SOFR
 
Administrator's
Website;
SOFR Administrator
means the Federal Reserve Bank of New York
 
(or a successor
administrator of SOFR);
SOFR Administrator's
 
Website
means the website
 
of the Federal
 
Reserve Bank of
New York, or any successor source; and
Unadjusted
 
Benchmark
 
Replacement
means
 
the
 
Benchmark
 
Replacement
excluding the Benchmark Replacement Adjustment.
(c)
 
Accrual of Interest
Each
 
Note
 
(or
 
in
 
the
 
case
 
of
 
the
 
redemption
 
of
 
part
 
only
 
of
 
a
 
Note,
 
that
 
part
 
only
 
of
 
such
Note) will
 
cease to
 
bear interest
 
(if any)
 
from the
 
date for
 
its redemption
 
unless payment
 
of
principal is improperly withheld or refused. In such event, interest will continue to accrue until
whichever is the earlier of:
(i)
 
the date on which
 
all amounts due in
 
respect of such Note
 
have been paid; and
(ii)
 
five days after the
 
date on which the
 
full amount of the
 
moneys payable in respect
 
of
such Note has been received by the Agent and notice to that effect has been given to
the Noteholders in accordance with Condition
 
(
Notices
).
4.
 
Payments
(a)
 
Method of Payment
Subject as provided
 
below:
(i)
 
payments
 
in
 
a
 
Specified
 
Currency
 
other
 
than
 
euro
 
will
 
be
 
made
 
by
 
transfer
 
to
 
an
account
 
in
 
the
 
relevant
 
Specified
 
Currency
 
maintained
 
by
 
the
 
payee
 
with,
 
or
 
at
 
the
option of
 
the payee by
 
a cheque in
 
such Specified Currency
 
drawn on, a
 
bank in
 
the
principal
 
financial
 
centre
 
of
 
the
 
country
 
of
 
such
 
Specified
 
Currency
 
(which,
 
if
 
the
Specified Currency is New Zealand dollars, shall be Auckland);
 
and
(ii)
 
payments
 
in euro
 
will be
 
made by
 
credit
 
or transfer
 
to
 
a euro
 
account (or
 
any other
account
 
to
 
which
 
euro
 
may
 
be
 
credited
 
or
 
transferred)
 
specified
 
by
 
the
 
payee
 
or
 
at
the option of the payee, by a euro cheque.
Payments
 
will be
 
subject in
 
all
 
cases to
 
any fiscal
 
or
 
other laws
 
and regulations
 
applicable
thereto
 
in
 
the
 
place
 
of
 
payment,
 
but
 
without
 
prejudice
 
to
 
the
 
provisions
 
of
 
Condition
(
Taxation
).
(b)
 
Presentation of definitive
 
Notes and Coupons
Payments of principal in respect of
 
definitive Notes will (subject as provided below)
 
be made
in the
 
manner provided in
 
paragraph
 
only against
 
presentation and surrender
 
(or,
in the case of part payment of
 
any sum due, endorsement)
 
of definitive Notes, and payments
0010155-0003327 UKO2:
 
2004375908.9
75
of
 
interest
 
in
 
respect
 
of
 
definitive
 
Notes
 
will
 
(subject
 
as
 
provided
 
below)
 
be
 
made
 
as
aforesaid
 
only
 
against
 
presentation
 
and
 
surrender
 
(or,
 
in
 
the
 
case
 
of
 
part
 
payment
 
of
 
any
sum due, endorsement) of Coupons, in each case at the specified office of any Paying Agent
outside
 
the
 
United
 
States
 
(which
 
expression,
 
as
 
used
 
herein,
 
means
 
the
 
United
 
States
 
of
America (including the States and the District of Columbia and its possessions)).
Fixed
 
Rate
 
Notes
 
in
 
definitive
 
form
 
should
 
be
 
presented
 
for
 
payment
 
together
 
with
 
all
unmatured
 
Coupons
 
appertaining
 
thereto
 
(which
 
expression
 
shall
 
for
 
this
 
purpose
 
include
Coupons falling
 
to
 
be
 
issued on
 
exchange
 
of matured
 
Talons),
 
failing which
 
the
 
amount
 
of
any missing unmatured Coupon (or,
 
in the case of payment not
 
being made in full, the same
proportion
 
of
 
the
 
amount
 
of
 
such missing
 
unmatured
 
Coupon as
 
the
 
sum
 
so
 
paid
 
bears to
the sum
 
due) will
 
be deducted
 
from the
 
sum due
 
for payment.
 
Each amount
 
of principal
 
so
deducted
 
will
 
be
 
paid
 
in
 
the
 
manner
 
mentioned
 
above
 
against
 
surrender
 
of
 
the
 
relative
missing
 
Coupon
 
at
 
any
 
time
 
before
 
the
 
expiry
 
of
 
10
 
years
 
after
 
the
 
Relevant
 
Date
 
(as
defined in
 
Condition
 
(
Taxation
)) in
 
respect of
 
such principal
 
(whether or
 
not such
 
Coupon
would
 
otherwise
 
have
 
become
 
void
 
under
 
Condition 7
 
(
Prescription
))
 
or,
 
if
 
later,
 
five
 
years
from
 
the
 
date
 
on
 
which
 
such
 
Coupon
 
would
 
otherwise
 
have
 
become
 
due,
 
but
 
in
 
no
 
event
thereafter.
Upon any Fixed Rate Note in definitive form becoming due and repayable
 
prior to its Maturity
Date,
 
all
 
unmatured
 
Talons
 
(if
 
any)
 
appertaining
 
thereto
 
will
 
become
 
void
 
and
 
no
 
further
Coupons will be issued in respect thereof.
Upon
 
the
 
date
 
on
 
which
 
any
 
Floating
 
Rate
 
Note
 
in
 
definitive
 
form
 
becomes
 
due
 
and
repayable, unmatured Coupons and Talons (if any) relating thereto (whether or not attached)
shall become
 
void
 
and no
 
payment or,
 
as the
 
case may
 
be, exchange
 
for further
 
Coupons
shall be made in respect thereof.
If the due date for redemption of any definitive Note is not an Interest Payment Date, interest
(if any) accrued in respect
 
of such Note from (and including) the
 
preceding Interest Payment
Date
 
or,
 
as
 
the
 
case
 
may
 
be,
 
the
 
Interest
 
Commencement
 
Date
 
shall
 
be
 
payable
 
only
against surrender of the relevant definitive Note.
(c)
 
Payments in respect
 
of global Notes
Payments
 
of
 
principal
 
and
 
interest
 
(if
 
any)
 
in
 
respect
 
of
 
Notes
 
represented
 
by
 
any
 
global
Note will
 
(subject as
 
provided below)
 
be made
 
in the
 
manner specified
 
above in
 
relation to
definitive
 
Notes
 
or
 
otherwise
 
in
 
the
 
manner
 
specified
 
in
 
the
 
relevant
 
global
 
Note,
 
where
applicable against presentation or surrender,
 
as the case may be,
 
of such global Note at
 
the
specified office of any Paying Agent outside the United States.
A
 
record
 
of
 
each
 
payment
 
made
 
against
 
presentation
 
or
 
surrender
 
of
 
such
 
global
 
Note,
distinguishing between
 
any payment
 
of principal
 
and any
 
payment of
 
interest, will
 
be made
on such global Note either by the Paying Agent to which it was presented or in the records of
Euroclear and Clearstream, Luxembourg, as applicable.
(d)
 
General provisions applicable
 
to payments
The holder
 
of a global
 
Note shall be
 
the only person
 
entitled to receive
 
payments in respect
of
 
Notes
 
represented
 
by
 
such
 
global
 
Note
 
and
 
the
 
Issuer
 
or,
 
as
 
the
 
case
 
may
 
be,
 
the
Guarantor
 
will
 
be
 
discharged
 
by
 
payment
 
to,
 
or
 
to
 
the
 
order
 
of,
 
the
 
holder
 
of
 
such
 
global
Note
 
in
 
respect
 
of
 
each
 
amount
 
so
 
paid.
 
Each
 
of
 
the
 
persons
 
shown
 
in
 
the
 
records
 
of
Euroclear
 
or
 
Clearstream,
 
Luxembourg
 
as
 
the
 
beneficial
 
holder
 
of
 
a
 
particular
 
nominal
amount
 
of
 
Notes
 
represented
 
by
 
such
 
global
 
Note
 
must
 
look
 
solely
 
to
 
Euroclear
 
or
0010155-0003327 UKO2:
 
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76
Clearstream, Luxembourg, as the case may
 
be, for their share of
 
each payment so made by
the
 
Issuer
 
or,
 
as the
 
case may
 
be,
 
the
 
Guarantor to,
 
or
 
to
 
the
 
order
 
of,
 
the
 
holder
 
of
 
such
global Note.
Notwithstanding the
 
foregoing provisions
 
of this
 
Condition, if
 
any amount
 
of principal
 
and/or
interest in respect of
 
Notes is payable in
 
U.S. dollars, such U.S.
 
dollar payments of principal
and/or
 
interest
 
in
 
respect
 
of
 
such
 
Notes
 
will
 
be
 
made
 
at
 
the
 
specified
 
office
 
of
 
a
 
Paying
Agent in the United States if:
(i)
 
the
 
Issuer
 
has
 
appointed
 
Paying
 
Agents
 
with
 
specified
 
offices
 
outside
 
the
 
United
States
 
with
 
the
 
reasonable
 
expectation
 
that
 
such
 
Paying
 
Agents
 
would
 
be
 
able
 
to
make payment in U.S. dollars at such
 
specified offices outside the United States of the
full amount
 
of principal
 
and interest
 
on the
 
Notes in the
 
manner provided above
 
when
due;
(ii)
 
payment
 
of
 
the
 
full
 
amount
 
of
 
such
 
principal
 
and
 
interest
 
at
 
all
 
such
 
specified
 
offices
outside
 
the
 
United
 
States
 
is
 
illegal
 
or
 
effectively
 
precluded
 
by
 
exchange
 
controls
 
or
other similar
 
restrictions on
 
the full
 
payment or
 
receipt of
 
principal and interest
 
in U.S.
dollars; and
(iii)
 
such
 
payment
 
is
 
then
 
permitted
 
under
 
United
 
States
 
law
 
without
 
involving,
 
in
 
the
opinion of the
 
Issuer and the
 
Guarantor (in the
 
case of Notes
 
having the benefit
 
of the
Guarantee), adverse tax consequences to the Issuer and the Guarantor (in the
 
case of
Notes having the benefit of the Guarantee).
(e)
 
Payment Day
If
 
the
 
date
 
for
 
payment of
 
any amount
 
in
 
respect of
 
any Note
 
or
 
Coupon is
 
not
 
a Payment
Day,
 
the holder thereof shall not be
 
entitled to payment until the next
 
following Payment Day
in the
 
relevant place
 
and shall
 
not be
 
entitled to
 
further interest
 
or other
 
payment in
 
respect
of
 
such
 
delay.
 
For
 
these
 
purposes,
Payment
 
Day
means
 
any
 
day
 
which
 
(subject
 
to
Condition 7 (
Prescription
)) is:
(i)
 
a
 
day
 
on
 
which
 
commercial
 
banks
 
and
 
foreign
 
exchange
 
markets
 
settle
 
payments
and are open for general
 
business (including dealing in foreign exchange and
 
foreign
currency deposits) in:
(a)
 
in the case of Notes
 
in definitive form only, the relevant place
 
of presentation;
(b)
 
each Additional Financial Centre (other than TARGET2 System) specified in
the applicable Final Terms;
(ii)
 
if
 
TARGET2
 
System
 
is
 
specified
 
as
 
an
 
Additional
 
Financial
 
Centre
 
in
 
the
 
applicable
Final Terms,
 
a day on which the TARGET2 System is open; and
(iii)
 
either (1) in relation to any sum payable in a Specified Currency other
 
than euro, a day
on
 
which
 
commercial
 
banks
 
and
 
foreign
 
exchange
 
markets
 
settle
 
payments
 
and
 
are
open for general
 
business (including dealing in
 
foreign exchange and
 
foreign currency
deposits)
 
in
 
the
 
principal
 
financial
 
centre
 
of
 
the
 
country
 
of
 
the
 
relevant
 
Specified
Currency (which if the Specified
 
Currency is New Zealand dollars
 
shall be Auckland) or
(2)
 
in
 
relation
 
to
 
any
 
sum
 
payable
 
in
 
euro,
 
a
 
day
 
on
 
which
 
the
 
TARGET2
 
System
 
is
open.
0010155-0003327 UKO2:
 
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(f)
 
Interpretation of Principal
 
and Interest
Any
 
reference
 
in
 
these
 
Terms
 
and
 
Conditions
 
to
 
principal
 
in
 
respect
 
of
 
the
 
Notes
 
shall
 
be
deemed to include, as applicable:
(i)
 
any
 
additional
 
amounts
 
which
 
may
 
be
 
payable
 
with
 
respect
 
to
 
principal
 
under
Condition 6 (
Taxation
);
(ii)
 
the Final Redemption Amount
 
of the Notes;
(iii)
 
the Early Redemption
 
Amount of the Notes;
(iv)
 
the Optional Redemption
 
Amount(s) (if any) of
 
the Notes;
(v)
 
the Make-Whole Redemption
 
Amount(s) (if any)
 
of the Notes;
(vi)
 
the Residual Call
 
Early Redemption Amount
 
(if any) of the Notes;
 
and
(vii)
 
any
 
premium
 
and
 
any
 
other
 
amounts
 
(other
 
than
 
interest)
 
which
 
may
 
be
 
payable
 
by
the Issuer under or in respect of the Notes.
Any
 
reference
 
in
 
these
 
Terms
 
and
 
Conditions
 
to
 
interest
 
in
 
respect
 
of
 
the
 
Notes
 
shall
 
be
deemed
 
to
 
include,
 
as
 
applicable,
 
any
 
additional
 
amounts
 
which
 
may
 
be
 
payable
 
with
respect to interest under Condition 6 (
Taxation
).
5.
 
Redemption and Purchase
(a)
 
At Maturity
Unless previously redeemed
 
or purchased and
 
cancelled as specified
 
below,
 
each Note will
be redeemed by the Issuer at its Final Redemption Amount specified in, or determined in the
manner
 
specified
 
in,
 
the
 
applicable
 
Final
 
Terms
 
in
 
the
 
relevant
 
Specified
 
Currency
 
on
 
the
Maturity Date.
(b)
 
Redemption for Tax Reasons
The Notes may be redeemed at
 
the option of the Issuer in
 
whole, but not in part,
 
at any time
(if this
 
Note is
 
not a
 
Floating Rate
 
Note) or
 
on any
 
Interest Payment
 
Date (if
 
this Note
 
is a
Floating
 
Rate
 
Note),
 
on
 
giving
 
not
 
less
 
than
 
30
 
nor
 
more
 
than
 
60
 
days'
 
notice
 
to
 
the
Noteholders (which notice shall be irrevocable), if:
(i)
 
on
 
the
 
occasion
 
of
 
the
 
next
 
payment
 
due
 
under
 
the
 
Notes,
 
the
 
Issuer
 
has
 
or
 
will
become
 
obliged
 
to
 
pay
 
additional
 
amounts
 
as
 
provided
 
or
 
referred
 
to
 
in
 
Condition
 
6
(
Taxation
) or (in
 
the case of
 
Notes having the
 
benefit of the
 
Guarantee) the Guarantor
would be
 
unable for
 
reasons outside
 
its control
 
to procure
 
payment by
 
the Issuer
 
and
in
 
making
 
payment
 
itself
 
would
 
be
 
required
 
to
 
pay
 
such
 
additional
 
amounts,
 
in
 
each
case
 
as
 
a
 
result
 
of
 
any
 
change
 
in,
 
or
 
amendment
 
to,
 
the
 
laws
 
or
 
regulations
 
of
 
the
Kingdom
 
of
 
Norway
 
or
 
any
 
political
 
subdivision
 
or
 
any
 
authority
 
thereof
 
or
 
therein
having power
 
to
 
tax, or
 
any change
 
in the
 
application or
 
official interpretation
 
of such
laws
 
or
 
regulations,
 
which
 
change
 
or
 
amendment
 
becomes
 
effective
 
on
 
or
 
after
 
the
Issue Date of the first Tranche of the Notes; and
0010155-0003327 UKO2:
 
2004375908.9
78
(ii)
 
such obligation cannot be avoided by the Issuer or,
 
as the case may be, the Guarantor
(in the case of Notes having the benefit of the Guarantee) taking reasonable measures
available to it,
provided
 
that
 
no
 
such
 
notice
 
of
 
redemption
 
shall
 
be
 
given
 
earlier
 
than
 
90
 
days
 
(or,
 
in
 
the
case
 
of
 
Floating
 
Rate
 
Notes,
 
a
 
number
 
of
 
days
 
which
 
is
 
equal
 
to
 
the
 
aggregate
 
of
 
the
number of
 
days falling within
 
the then
 
current interest period
 
applicable to the
 
Floating Rate
Notes plus 60 days) prior to the earliest date on which the Issuer or,
 
as the case may be, the
Guarantor (in the case of Notes having the benefit of the Guarantee) would be obliged
 
to pay
such additional amounts were a payment in respect of the Notes
 
then due.
Prior
 
to
 
the
 
publication
 
of
 
any
 
notice
 
of
 
redemption
 
pursuant
 
to
 
this
 
Condition
 
5(b)
(
Redemption for
 
Tax
 
Reasons
), the
 
Issuer shall
 
deliver to
 
the
 
Agent a
 
certificate signed
 
by
one director of
 
the Issuer or,
 
as the case
 
may be, one
 
director of the
 
Guarantor (in the
 
case
of Notes having the
 
benefit of the Guarantee) stating that
 
the Issuer is entitled to
 
effect such
redemption
 
and
 
setting
 
forth
 
a
 
statement
 
of
 
facts
 
showing
 
that
 
the
 
conditions precedent
 
to
the
 
right
 
of
 
the
 
Issuer
 
so
 
to
 
redeem
 
have
 
occurred,
 
and
 
an
 
opinion
 
of
 
independent
 
legal
advisers
 
of
 
recognised
 
standing
 
to
 
the
 
effect
 
that
 
the
 
Issuer
 
or,
 
as
 
the
 
case
 
may
 
be,
 
the
Guarantor
 
(in
 
the
 
case
 
of
 
Notes
 
having
 
the
 
benefit
 
of
 
the
 
Guarantee)
 
has
 
or
 
will
 
become
obliged to pay such additional amounts as a result of such
 
change or amendment.
Notes
 
redeemed
 
pursuant
 
to
 
this
 
Condition
 
5(b)
 
(
Redemption
 
for
 
Tax
 
Reasons
)
 
will
 
be
redeemed at
 
their Early
 
Redemption Amount
 
referred to
 
in paragraph
 
together (if
appropriate) with interest accrued to (but excluding) the date of
 
redemption.
(c)
 
Redemption at the
 
Option of the Issuer
 
(Issuer Call)
If Issuer
 
Call is
 
specified as
 
being applicable in
 
the applicable Final
 
Terms,
 
the Issuer
 
shall,
having given:
(i)
 
not less than 15 nor more than 30 days' notice to the Noteholders in
 
accordance with
Condition
 
(
Notices
); and
(ii)
 
not
 
less than
 
15 days
 
before the giving
 
of
 
the
 
notice referred
 
to
 
in
 
(i),
 
notice to the
Agent;
(which
 
notices
 
shall
 
be
 
irrevocable),
 
redeem
 
all
 
or,
 
if
 
so
 
specified
 
in
 
the
 
applicable
 
Final
Terms,
 
some only
 
of
 
the
 
Notes then
 
outstanding on
 
any Optional
 
Redemption Date
 
and at
the
 
Optional
 
Redemption Amount(s)
 
specified
 
in, or
 
determined in
 
the
 
manner
 
specified in,
the
 
applicable Final
 
Terms
 
together,
 
if
 
appropriate,
 
with
 
interest
 
accrued
 
to
 
(but
 
excluding)
the relevant Optional
 
Redemption Date. Any
 
such redemption must
 
be of a
 
nominal amount
not
 
less
 
than
 
the
 
Minimum
 
Redemption
 
Amount
 
and
 
not
 
more
 
than
 
a
 
Higher
 
Redemption
Amount
 
in
 
each
 
case
 
as
 
may
 
be
 
specified
 
in
 
the
 
applicable
 
Final
 
Terms.
 
In
 
the
 
case
 
of
 
a
partial redemption
 
of Notes,
 
the Notes
 
to be
 
redeemed (
Redeemed Notes
) will
 
be selected
individually
 
by
 
lot,
 
in
 
the
 
case
 
of
 
Redeemed
 
Notes represented
 
by
 
definitive
 
Notes,
 
and
 
in
accordance with
 
the rules
 
of Euroclear
 
and/or Clearstream,
 
Luxembourg, (to
 
be reflected
 
in
the records of Euroclear and Clearstream, Luxembourg as
 
either a pool factor or a
 
reduction
in
 
nominal
 
amount,
 
at
 
their
 
discretion)
 
in
 
the
 
case
 
of
 
Redeemed
 
Notes
 
represented
 
by
 
a
global
 
Note,
 
not
 
more
 
than
 
30
 
days
 
prior
 
to
 
the
 
date
 
fixed
 
for
 
redemption
 
(such
 
date
 
of
selection
 
being
 
hereinafter
 
called
 
the
Selection
 
Date
).
 
In
 
the
 
case
 
of
 
Redeemed
 
Notes
represented by definitive Notes, a
 
list of the serial
 
numbers of such Redeemed Notes
 
will be
published in
 
accordance with
 
Condition
 
(
Notices
) not
 
less than
 
15 days
 
prior to
 
the date
fixed
 
for
 
redemption.
 
No
 
exchange
 
of
 
the
 
relevant
 
global
 
Note
 
will
 
be
 
permitted
 
during
 
the
period
 
from
 
(and
 
including)
 
the
 
Selection
 
Date
 
to
 
(and
 
including)
 
the
 
date
 
fixed
 
for
0010155-0003327 UKO2:
 
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redemption
 
pursuant
 
to
 
this
 
paragraph
 
and
 
notice
 
to
 
that
 
effect
 
shall
 
be
 
given
 
by
 
the
Issuer to the Noteholders
 
in accordance with Condition
 
(
Notices
) at least 15
 
days prior to
the Selection Date.
(d)
 
Make-Whole Redemption
If
 
Make-Whole
 
Redemption
 
is
 
specified
 
as
 
being
 
applicable
 
in
 
the
 
applicable
 
Final
 
Terms,
the Issuer
 
may,
 
having given
 
not less
 
than 15
 
nor more
 
than 60
 
days' notice
 
(or such
 
other
notice
 
period
 
as
 
may
 
be
 
specified
 
in
 
the
 
applicable
 
Final
 
Terms)
 
to
 
the
 
Noteholders
 
in
accordance with
 
Condition
 
(
Notices
) (which
 
notice shall
 
be irrevocable
 
and shall
 
specify
the
 
date
 
fixed
 
for
 
redemption
 
(the
Make-Whole
 
Redemption
 
Date
)),
 
redeem
 
all
 
or
 
(if
redemption in part
 
is specified
 
as being
 
applicable in the
 
applicable Final Terms)
 
some only
of the Notes then outstanding on any Make-Whole Redemption Date and at the Make-Whole
Redemption
 
Amount
 
together,
 
if
 
appropriate,
 
with
 
interest
 
accrued
 
to
 
(but
 
excluding)
 
the
relevant Make-Whole Redemption Date. If redemption in part is specified as being applicable
in
 
the
 
applicable Final
 
Terms,
 
any
 
such redemption
 
must
 
be
 
of
 
a
 
nominal amount
 
not
 
less
than
 
the
 
Minimum
 
Redemption
 
Amount
 
and
 
not
 
more
 
than
 
the
 
Maximum
 
Redemption
Amount in each case as may be specified in the applicable
 
Final Terms.
In
 
the
 
case
 
of
 
a
 
partial
 
redemption
 
of
 
Notes,
 
the
 
Redeemed
 
Notes
 
will
 
be
 
selected
individually
 
by
 
lot,
 
in
 
the
 
case
 
of
 
Redeemed
 
Notes
 
represented
 
by
 
definitive
 
Notes,
 
and
 
in
accordance with
 
the rules
 
of
 
Euroclear and/or
 
Clearstream, Luxembourg
 
(to
 
be reflected
 
in
the records of Euroclear and Clearstream, Luxembourg as
 
either a pool factor or a
 
reduction
in
 
nominal
 
amount,
 
at
 
their
 
discretion),
 
in
 
the
 
case
 
of
 
Redeemed
 
Notes
 
represented
 
by
 
a
Global
 
Note,
 
on
 
a
 
Selection
 
Date
 
not
 
more
 
than
 
30
 
days
 
prior
 
to
 
the
 
Make-Whole
Redemption Date.
 
In the
 
case of
 
Redeemed Notes
 
represented by
 
definitive Notes,
 
a list
 
of
the serial numbers
 
of such Redeemed
 
Notes will be
 
published in accordance
 
with Condition
 
(
Notices
) not less than
 
15 days prior to
 
the Make-Whole Redemption Date.
 
No exchange
of
 
the
 
relevant
 
Global
 
Note
 
will
 
be
 
permitted
 
during
 
the
 
period
 
from
 
(and
 
including)
 
the
Selection
 
Date
 
to
 
(and
 
including)
 
the
 
Make-Whole
 
Redemption
 
Date
 
pursuant
 
to
 
this
paragraph
 
and
 
notice
 
to
 
that
 
effect
 
shall
 
be
 
given
 
by
 
the
 
Issuer
 
to
 
the
 
Noteholders
 
in
accordance with Condition
2 (
Notices
) at least 15 days prior to the Selection Date.
In
 
this
 
Condition
 
5(d)
 
(
Make-Whole
 
Redemption
),
Make-Whole
 
Redemption
 
Amount
means (A) the outstanding principal amount of
 
the relevant Note or (B)
 
if higher, the
 
sum, as
determined
 
by
 
the
 
Make-Whole
 
Calculation
 
Agent,
 
of
 
the
 
present
 
values
 
of
 
the
 
remaining
scheduled
 
payments
 
of
 
principal
 
and
 
interest
 
on
 
the
 
Notes
 
to
 
be
 
redeemed
 
(not
 
including
any
 
portion
 
of
 
such
 
payments
 
of
 
interest
 
accrued
 
to
 
the
 
date
 
of
 
redemption)
 
discounted to
the Make-Whole Redemption Date on an annual basis at the Reference Rate plus the Make-
Whole Redemption Margin specified in the applicable Final
 
Terms,
 
where:
CA
 
Selected
 
Bond
means
 
a
 
government
 
security
 
or
 
securities
 
(which,
 
if
 
the
 
Specified
Currency
 
is
 
euro,
 
will
 
be
 
a
 
German
 
Bundesobligationen)
 
selected
 
by
 
the
 
Make-Whole
Calculation Agent as
 
having a maturity comparable
 
to the remaining
 
term of the
 
Notes to be
redeemed that
 
would be
 
utilised, at
 
the time
 
of selection
 
and in
 
accordance with
 
customary
financial practice,
 
in pricing
 
new issues
 
of corporate
 
debt securities
 
of comparable
 
maturity
to the remaining term of such Notes;
Make-Whole
 
Calculation
 
Agent
means
 
an
 
independent
 
investment,
 
merchant
 
or
commercial bank or financial institution selected by the Issuer for
 
the purposes of calculating
the
 
Make-Whole
 
Redemption
 
Amount,
 
and
 
notified
 
to
 
the
 
Noteholders
 
in
 
accordance
 
with
Condition
 
(
Notices
);
0010155-0003327 UKO2:
 
2004375908.9
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Reference Bond
means (A) if
 
CA Selected Bond
 
is specified in
 
the applicable Final
 
Terms,
the relevant
 
CA Selected
 
Bond or
 
(B) if
 
CA Selected
 
Bond is
 
not specified
 
in the
 
applicable
Final Terms,
 
the security
 
specified in
 
the applicable
 
Final Terms,
 
provided that
 
if the
 
Make-
Whole
 
Calculation Agent
 
advises
 
the
 
Issuer
 
that,
 
for
 
reasons
 
of
 
illiquidity
 
or
 
otherwise, the
relevant
 
security
 
specified
 
is
 
not
 
appropriate
 
for
 
such
 
purpose,
 
such
 
other
 
central
 
bank
 
or
government
 
security
 
as
 
the
 
Make-Whole
 
Calculation
 
Agent
 
may,
 
with
 
the
 
advice
 
of
Reference Market Makers, determine to be appropriate;
Reference Bond
 
Price
means (i) the
 
average of three
 
Reference Market Maker Quotations
for
 
the
 
relevant
 
Make-Whole
 
Redemption
 
Date,
 
after
 
excluding
 
the
 
highest
 
and
 
lowest
Reference Market Maker
 
Quotations, (ii) if
 
the Make-Whole Calculation
 
Agent obtains fewer
than three, but
 
more than one,
 
such Reference Market Maker
 
Quotations, the average
 
of all
such quotations,
 
or (iii)
 
if only
 
one such
 
Reference Market Maker
 
Quotation is
 
obtained, the
amount of the Reference Market Maker Quotation so obtained;
Reference
 
Market
 
Maker
 
Quotations
means,
 
with
 
respect
 
to
 
each
 
Reference
 
Market
Maker
 
and
 
any
 
Make-Whole
 
Redemption
 
Date,
 
the
 
average,
 
as
 
determined
 
by
 
the
 
Make-
Whole Calculation Agent,
 
of the bid
 
and asked prices
 
for the
 
Reference Bond (expressed
 
in
each
 
case
 
as
 
a
 
percentage
 
of
 
its
 
principal
 
amount)
 
quoted
 
in
 
writing
 
to
 
the
 
Make-Whole
Calculation
 
Agent
 
at
 
the
 
Quotation
 
Time
 
specified
 
in
 
the
 
applicable
 
Final
 
Terms
 
on
 
the
Reference Rate Determination Day specified in the applicable
 
Final Terms;
Reference Market
 
Makers
means three brokers or market
 
makers of securities such as
 
the
Reference Bond selected by the Make-Whole
 
Calculation Agent or such other three
 
persons
operating
 
in
 
the
 
market
 
for
 
securities
 
such
 
as
 
the
 
Reference
 
Bond
 
as
 
are
 
selected
 
by
 
the
Make-Whole Calculation Agent in consultation with the Issuer; and
Reference
 
Rate
means,
 
with
 
respect
 
to
 
any
 
Make-Whole
 
Redemption
 
Date,
 
the
 
rate
 
per
annum
 
equal
 
to
 
the
 
equivalent yield
 
to
 
maturity of
 
the
 
Reference Bond,
 
calculated
 
using
 
a
price
 
for
 
the
 
Reference Bond
 
(expressed
 
as
 
a
 
percentage of
 
its
 
principal amount)
 
equal to
the Reference Bond
 
Price for such
 
Make-Whole Redemption Date.
 
The Reference Rate
 
will
be
 
calculated
 
on
 
the
 
Reference
 
Rate
 
Determination
 
Day
 
specified
 
in
 
the
 
applicable
 
Final
Terms.
(e)
 
Issuer Residual Call
If Issuer
 
Residual Call is
 
specified as
 
being applicable in
 
the applicable
 
Final Terms
 
and, at
any time, the outstanding aggregate nominal amount
 
of the Notes is equal to
 
or less than 25
per
 
cent.
 
(or
 
such
 
other
 
percentage
 
as
 
may
 
be
 
specified
 
in
 
the
 
applicable
 
Final
 
Terms
 
as
being
 
the
 
Residual
 
Call
 
Threshold)
 
of
 
the
 
aggregate
 
nominal
 
amount
 
of
 
the
 
Series
 
issued
(other
 
than
 
as
 
a
 
result
 
of
 
a
 
partial
 
redemption
 
of
 
the
 
Notes
 
pursuant
 
to
 
Condition
 
5(c)
(
Redemption
 
at
 
the
 
Option
 
of
 
the
 
Issuer
 
(Issuer
 
Call)
)
 
or
 
Condition
 
5(d)
 
(
Make-Whole
Redemption
)),
 
the
 
Notes may
 
be
 
redeemed at
 
the
 
option
 
of
 
the
 
Issuer
 
in whole,
 
but
 
not
 
in
part, at any time (if this Note is
 
not a Floating Rate Note) or on any Interest
 
Payment Date (if
this
 
Note
 
is
 
a
 
Floating Rate
 
Note),
 
on
 
giving
 
not
 
less
 
than
 
15
 
and
 
not
 
more
 
than
 
60
 
days’
notice (or such
 
other notice period
 
as may be
 
specified in the
 
applicable Final Terms)
 
to the
Noteholders
 
in
 
accordance
 
with
 
Condition
 
12
 
(
Notices
)
 
(which
 
notice
 
shall
 
be
 
irrevocable
and
 
shall
 
specify
 
the
 
date
 
fixed
 
for
 
redemption)
 
at
 
the
 
Residual
 
Call
 
Early
 
Redemption
Amount
 
together,
 
if
 
appropriate,
 
with
 
interest
 
accrued
 
to
 
(but
 
excluding)
 
the
 
date
 
of
redemption.
0010155-0003327 UKO2:
 
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(f)
 
Redemption at the
 
Option of the Noteholders
 
(Investor Put)
If Investor Put is specified as being applicable in the
 
applicable Final Terms,
 
upon the holder
of any
 
Note giving
 
to the
 
Issuer in
 
accordance with
 
Condition 12
 
(
Notices
) not
 
less than
 
15
nor
 
more
 
than
 
30
 
days'
 
notice
 
the
 
Issuer
 
will,
 
upon
 
the
 
expiry
 
of
 
such
 
notice,
 
redeem,
 
in
whole
 
(but
 
not
 
in
 
part),
 
such
 
Note
 
on
 
the
 
Optional
 
Redemption
 
Date
 
and
 
at
 
the
 
Optional
Redemption
 
Amount
 
specified
 
in
 
the
 
applicable
 
Final
 
Terms
 
together,
 
if
 
appropriate,
 
with
interest accrued to (but excluding) the Optional Redemption Date.
If this Note is
 
in definitive form and held outside Euroclear
 
and Clearstream, Luxembourg, to
exercise the right to require redemption of this Note the holder of this Note must deliver such
Note at the specified office
 
of any Paying Agent at any
 
time during normal business hours of
such
 
Paying
 
Agent
 
falling
 
within
 
the
 
notice
 
period,
 
accompanied
 
by
 
a
 
duly
 
completed
 
and
signed
 
notice
 
of
 
exercise
 
in
 
the
 
form
 
(for
 
the
 
time
 
being
 
current)
 
obtainable
 
from
 
any
specified office
 
of any
 
Paying Agent
 
(a
Put
 
Notice
) and
 
in which
 
the holder
 
must specify
 
a
bank
 
account
 
(or,
 
if
 
payment
 
is
 
by
 
cheque,
 
an
 
address)
 
to
 
which
 
payment
 
is
 
to
 
be
 
made
under this Condition
 
accompanied by this
 
Note or evidence
 
satisfactory to the
 
Paying Agent
concerned
 
that
 
this
 
Note
 
will,
 
following
 
delivery
 
of
 
the
 
Put
 
Notice,
 
be
 
held
 
to
 
its
 
order
 
or
under its control. If
 
this Note is
 
represented by a global
 
Note or is
 
in definitive form and
 
held
through
 
Euroclear or
 
Clearstream, Luxembourg,
 
to
 
exercise the
 
right to
 
require redemption
of this Note the
 
holder of this Note
 
must, within the notice period,
 
give notice to the
 
Agent of
such
 
exercise
 
in
 
accordance
 
with
 
the
 
standard
 
procedures
 
of
 
Euroclear
 
and
 
Clearstream,
Luxembourg
 
(which
 
may
 
include
 
notice
 
being
 
given
 
on
 
their
 
instruction
 
by
 
Euroclear
 
or
Clearstream,
 
Luxembourg or
 
any
 
common
 
depositary
 
or
 
common
 
safekeeper,
 
as
 
the
 
case
may
 
be, for
 
them to
 
the Agent
 
by electronic
 
means) in
 
a form
 
acceptable to
 
Euroclear and
Clearstream, Luxembourg from time to time.
Any
 
Put
 
Notice
 
or
 
other
 
notice
 
given
 
in
 
accordance
 
with
 
the
 
standard
 
procedures
 
of
Euroclear
 
and
 
Clearstream,
 
Luxembourg
 
given
 
by
 
a
 
holder
 
of
 
any
 
Note
 
pursuant
 
to
 
this
paragraph shall be irrevocable except where
 
prior to the due date
 
of redemption an Event of
Default shall have
 
occurred and be
 
continuing in which event
 
such holder,
 
at its option,
 
may
elect
 
by
 
notice
 
to
 
the
 
Issuer
 
to
 
withdraw
 
the
 
notice
 
given
 
pursuant
 
to
 
this
 
paragraph
 
and
instead to
 
declare such
 
Note forthwith
 
due and
 
payable pursuant
 
to Condition
 
8 (
Events of
Default
).
(g)
 
Early Redemption Amounts
For the
 
purpose of
 
paragraph
 
and Condition
 
8 (
Events of
 
Default
), the
 
Notes will
be redeemed at the Early Redemption Amount calculated as
 
follows:
(i)
 
in the
 
case of
 
Notes with
 
a Final
 
Redemption Amount
 
equal to
 
the Issue
 
Price, at
 
the
Final Redemption Amount thereof;
(ii)
 
in the case
 
of Notes (other than
 
Zero Coupon Notes) with
 
a Final Redemption Amount
which
 
is
 
or
 
may
 
be
 
less
 
or
 
greater
 
than
 
the
 
Issue
 
Price
 
or
 
which
 
is
 
payable
 
in
 
a
Specified Currency other than that
 
in which the Notes
 
are denominated, at the amount
specified in, or
 
determined in the manner
 
specified in, the
 
applicable Final Terms
 
or,
 
if
no such amount or manner
 
is so specified in the
 
Final Terms,
 
at their nominal amount;
or
(iii)
 
in
 
the
 
case
 
of
 
Zero
 
Coupon
 
Notes,
 
at
 
its
 
Early
 
Redemption
 
Amount
 
calculated
 
in
accordance with the following formula:
Early Redemption Amount = RP
 
x (1 + AY)
y
0010155-0003327 UKO2:
 
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where:
RP
means the Reference
 
Price;
AY
means the Accrual Yield expressed
 
as a decimal; and
y
is
 
the
 
Day
 
Count
 
Fraction
 
specified
 
in
 
the
 
applicable
 
Final
 
Terms
 
which
 
will
 
be
either
 
(i)
 
30/360
 
(in
 
which
 
case
 
the
 
numerator
 
will
 
be
 
equal
 
to
 
the
 
number
 
of
 
days
(calculated on the
 
basis of
 
a 360 day
 
year consisting of
 
12 months of
 
30 days each)
from
 
(and
 
including)
 
the
 
Issue
 
Date
 
of
 
the
 
first
 
Tranche
 
of
 
the
 
Notes
 
to
 
(but
excluding) the date fixed for redemption or (as the case may be) the
 
date upon which
such
 
Note
 
becomes
 
due
 
and
 
repayable
 
and
 
the
 
denominator
 
will
 
be
 
360
 
(ii)
Actual/360 (in
 
which case
 
the
 
numerator will
 
be equal
 
to
 
the actual
 
number of
 
days
from
 
(and
 
including)
 
the
 
Issue
 
Date
 
of
 
the
 
first
 
Tranche
 
of
 
the
 
Notes
 
to
 
(but
excluding) the date fixed for redemption or (as the case may be) the
 
date upon which
such
 
Note
 
becomes
 
due
 
and
 
repayable
 
and
 
the
 
denominator
 
will
 
be
 
360)
 
or
 
(iii)
Actual/365 (in
 
which case
 
the
 
numerator will
 
be equal
 
to
 
the actual
 
number of
 
days
from
 
(and
 
including)
 
the
 
Issue
 
Date
 
of
 
the
 
first
 
Tranche
 
of
 
the
 
Notes
 
to
 
(but
excluding) the date fixed for redemption or (as the case may be) the
 
date upon which
such Note becomes due and repayable and the denominator will
 
be 365).
(h)
 
Purchases
The Issuer
 
or the Guarantor
 
(in the case
 
of Notes having
 
the benefit of
 
the Guarantee) may
at
 
any
 
time
 
purchase
 
Notes
 
(provided
 
that,
 
in
 
the
 
case
 
of
 
definitive
 
Notes,
 
all
 
unmatured
Coupons and Talons
 
appertaining thereto are
 
purchased therewith) at
 
any price in
 
the open
market or otherwise. Such Notes may be held, reissued, resold or,
 
at the option of the Issuer
or the
 
Guarantor (in
 
the case
 
of Notes
 
having the
 
benefit of
 
the Guarantee),
 
surrendered to
any Paying Agent for cancellation.
(i)
 
Cancellation
All
 
Notes
 
which
 
are
 
redeemed
 
will
 
forthwith
 
be
 
cancelled
 
(together
 
with
 
all
 
unmatured
Coupons attached
 
thereto or
 
surrendered therewith
 
at the
 
time of
 
redemption). All
 
Notes so
cancelled and the Notes purchased and cancelled pursuant to paragraph
 
(together
with all unmatured Coupons cancelled therewith) shall be forwarded to the Agent and cannot
be reissued or resold.
(j)
 
Late payment on Zero
 
Coupon Notes
If
 
the
 
amount
 
payable
 
in
 
respect
 
of
 
any
 
Zero
 
Coupon Note
 
upon
 
redemption of
 
such
 
Zero
Coupon Note
 
pursuant to
 
paragraph
,
,
,
 
(d),
 
(e) or
 
(f)
 
above or
 
upon
 
its
 
becoming
due
 
and repayable
 
as provided
 
in
 
Condition 8
 
(
Events of
 
Default
)
 
is improperly
 
withheld or
refused,
 
the
 
amount
 
due
 
and
 
repayable
 
in
 
respect
 
of
 
such
 
Zero
 
Coupon Note
 
shall
 
be the
amount calculated
 
as provided
 
in paragraph
 
as though
 
the references
 
therein
to
 
the
 
date
 
fixed
 
for
 
the
 
redemption
 
or
 
the
 
date
 
upon
 
which
 
such
 
Zero
 
Coupon
 
Note
becomes due and payable were replaced by references to
 
the date which is the earlier of:
(i)
 
the
 
date
 
on
 
which
 
all
 
amounts
 
due
 
in
 
respect
 
of
 
such
 
Zero
 
Coupon
 
Note
 
have
 
been
paid; and
(ii)
 
five
 
days
 
after
 
the
 
date
 
on
 
which
 
the
 
full
 
amount
 
of
 
the
 
moneys
 
payable
 
has
 
been
received
 
by
 
the
 
Agent and
 
notice
 
to
 
that
 
effect
 
has
 
been
 
given
 
to
 
the
 
Noteholders in
accordance with Condition 12 (
Notices
).
0010155-0003327 UKO2:
 
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83
6.
 
Taxation
All payments
 
of principal
 
and interest
 
in respect
 
of the
 
Notes and
 
Coupons by
 
the Issuer
 
or
(in the case
 
of Notes having the
 
benefit of the
 
Guarantee) the Guarantor shall
 
be made free
and
 
clear
 
of,
 
and
 
without
 
withholding
 
or
 
deduction
 
for,
 
any
 
taxes,
 
duties,
 
assessments
 
or
governmental
 
charges
 
(
Taxes
)
 
of
 
whatever
 
nature
 
imposed,
 
levied,
 
collected,
 
withheld
 
or
assessed
 
by
 
or
 
within
 
the
 
Kingdom
 
of
 
Norway
 
or
 
any
 
authority
 
therein
 
or
 
thereof
 
having
power
 
to
 
tax,
 
unless
 
such
 
withholding
 
or
 
deduction
 
is
 
required
 
by
 
law.
 
In
 
such
 
event,
 
the
Issuer or,
 
as the case
 
may be, the
 
Guarantor (in the
 
case of Notes
 
having the benefit
 
of the
Guarantee) shall
 
pay such
 
additional amounts
 
as will
 
result
 
in receipt
 
by the
 
holders of
 
the
Notes
 
or
 
Coupons
 
of
 
such
 
amounts
 
as
 
would
 
have
 
been
 
received
 
by
 
them
 
had
 
no
 
such
withholding
 
or
 
deduction
 
been
 
required,
 
except
 
that
 
no
 
such
 
additional
 
amounts
 
shall
 
be
payable with respect to any Note or Coupon:
(a)
 
presented for payment
 
in the Kingdom
 
of Norway; or
(b)
 
the
 
holder
 
or
 
beneficial
 
owner
 
of
 
which
 
is
 
liable
 
for
 
such
 
Taxes
 
in
 
respect
 
of
 
such
Note or Coupon
 
by reason of
 
the holder or
 
beneficial owner having some
 
connection
with the Kingdom
 
of Norway other than the mere holding of such Note
 
or Coupon; or
(c)
 
presented
 
for
 
payment
 
more
 
than
 
30
 
days
 
after
 
the
 
Relevant
 
Date
 
except
 
to
 
the
extent that the holder thereof would have been entitled to such additional amounts on
presenting the same for payment on such thirtieth day; or
(d)
 
on account of any
 
Taxes
 
that are payable pursuant to
 
the Norwegian Tax
 
Act section
10-80 on payments
 
to related companies
 
or undertakings (as
 
such term is
 
defined in
the
 
Norwegian Tax
 
Act section
 
10-82) tax
 
resident in
 
a
 
low-tax jurisdiction
 
(as
 
such
term is defined in the Norwegian Tax Act section 10-63).
In
 
addition,
 
any
 
amounts
 
to
 
be
 
paid
 
on
 
the
 
Notes
 
will
 
be
 
paid
 
net
 
of
 
any
 
deduction
 
or
withholding imposed or required pursuant to
 
sections 1471 through 1474 of
 
the U.S. Internal
Revenue
 
Code
 
of
 
1986
 
(or
 
any
 
regulations
 
thereunder
 
or
 
official
 
interpretations
 
thereof)
(
FATCA
)
 
or any
 
intergovernmental agreement
 
with
 
the
 
United States
 
to
 
implement FATCA
(
IGA
)
 
(or
 
any
 
law
 
implementing
 
such
 
an
 
intergovernmental
 
agreement),
 
and
 
no
 
additional
amounts will be required to be paid on account of any such deduction
 
or withholding.
Relevant
 
Date
means
 
whichever
 
is
 
the
 
later
 
of
 
(i)
 
the
 
date
 
on
 
which
 
such
 
payment
 
first
becomes
 
due
 
and (ii)
 
if
 
the
 
full
 
amount
 
payable has
 
not
 
been received
 
by the
 
Agent
 
on or
prior to such due date, the
 
date on which, the full amount
 
having been so received, notice to
that effect is duly given to the Noteholders in accordance with Condition 12
 
(
Notices
).
7.
 
Prescription
The
 
Notes
 
and
 
Coupons
 
will
 
become
 
void
 
unless
 
claims
 
in
 
respect
 
of
 
principal
 
and/or
interest are made
 
within a period
 
of 10 years
 
(in the case
 
of principal) and
 
five years (in
 
the
case of interest) after the Relevant Date therefor.
There shall not be included in any Coupon sheet issued on exchange of a Talon any Coupon
the
 
claim
 
for
 
payment
 
in
 
respect
 
of
 
which
 
would
 
be
 
void
 
pursuant
 
to
 
this
 
Condition
 
7
(
Prescription
) or
 
Condition 4(b) (
Presentation of definitive Notes
 
and Coupons)
or any Talon
which
 
would
 
be
 
void
 
pursuant
 
to
 
Condition
 
4(b)
 
(
Presentation
 
of
 
definitive
 
Notes
 
and
Coupons)
.
0010155-0003327 UKO2:
 
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84
8.
 
Events of Default
If
 
any
 
one
 
or
 
more
 
of
 
the
 
following
 
events
 
(each
 
an
Event
 
of
 
Default
)
 
shall
 
occur
 
and
 
is
continuing:
(a)
 
the Issuer
 
or (in the
 
case of
 
Notes having the
 
benefit of the
 
Guarantee) the Guarantor
fails
 
to
 
pay
 
any
 
principal
 
or
 
interest
 
on
 
any
 
of
 
the
 
Notes
 
when
 
due
 
and
 
such
 
failure
continues, in the case of principal or interest, for a period of 30 days;
 
or
(b)
 
the Issuer
 
or (in the
 
case of Notes
 
having the benefit
 
of the Guarantee)
 
the Guarantor
does not
 
perform or
 
comply with
 
any one
 
or more
 
of its
 
other obligations
 
in the
 
Notes
which default
 
is incapable
 
of remedy
 
or is
 
not remedied
 
within 90
 
days after
 
notice of
such
 
default
 
shall
 
have
 
been
 
given
 
to
 
the
 
Agent
 
at
 
its
 
specified
 
office
 
by
 
any
Noteholder; or
(c)
 
the Issuer
 
or (in the
 
case of Notes
 
having the benefit
 
of the Guarantee)
 
the Guarantor
is (or
 
is, or
 
could be,
 
deemed by
 
law or
 
a court
 
to be)
 
insolvent or
 
bankrupt or
 
unable
to
 
pay its
 
debts, stops,
 
suspends or
 
threatens to
 
stop or
 
suspend payment
 
of all
 
or a
material
 
part
 
of
 
(or
 
of
 
a
 
particular
 
type
 
of)
 
its
 
debts,
 
proposes
 
or
 
makes
 
a
 
general
assignment
 
or
 
an
 
arrangement
 
or
 
composition
 
with
 
or
 
for
 
the
 
benefit
 
of
 
the
 
relevant
creditors
 
in
 
respect
 
of
 
any
 
of
 
such
 
debts
 
or
 
a
 
moratorium
 
is
 
agreed
 
or
 
declared
 
in
respect
 
of
 
or
 
affecting
 
all
 
or
 
any
 
part
 
of
 
(or
 
of
 
a
 
particular
 
type
 
of)
 
the
 
debts
 
of
 
the
Issuer or (in the case of Notes having the benefit of the Guarantee)
 
the Guarantor; or
(d)
 
(A) an order is made or
 
an effective resolution passed for the
 
winding-up or dissolution
of
 
the
 
Issuer
 
or
 
(in
 
the
 
case
 
of
 
Notes
 
having
 
the
 
benefit
 
of
 
the
 
Guarantee)
 
the
Guarantor,
 
or
 
(B)
 
the
 
Issuer
 
or
 
(in
 
the
 
case
 
of
 
Notes
 
having
 
the
 
benefit
 
of
 
the
Guarantee) the Guarantor
 
ceases or threatens
 
to cease to
 
carry on all
 
or substantially
all of its business or operations, except:
(i)
 
(in the case of sub-paragraph
 
(B)) in the case of an
 
Asset Transfer;
(ii)
 
in the case of a
 
Permitted Reorganisation; or
(iii)
 
for
 
the
 
purpose
 
of
 
and
 
followed
 
by
 
any
 
other
 
reconstruction,
 
amalgamation,
reorganisation, merger or consolidation, on terms approved by an Extraordinary
Resolution of the Noteholders; or
(e)
 
other
 
than
 
in
 
respect
 
of
 
the
 
termination
 
of
 
the
 
Guarantee
 
pursuant
 
to
 
Condition
 
2(c)
(
Termination
 
of Guarantee
), if the
 
Guarantee ceases to
 
be, or is
 
claimed by the Issuer
or the Guarantor not to be, in full force and effect; or
(f)
 
any
 
event
 
occurs which
 
under the
 
laws of
 
any relevant
 
jurisdiction has
 
an analogous
effect to any of the events referred to in
 
to
then any Note may,
 
by notice given in writing to the Agent at its specified office by the holder
be declared
 
immediately due
 
and payable
 
whereupon it
 
shall become
 
immediately due
 
and
payable at the Early
 
Redemption Amount (as described in
 
Condition 5(g) (
Early Redemption
Amounts
)),
 
together
 
with
 
accrued
 
interest
 
(if
 
any)
 
to
 
the
 
date
 
of
 
repayment,
 
without
 
further
formality unless such
 
Event of Default
 
shall have been
 
remedied prior to
 
the receipt of
 
such
notice by the Agent.
As used herein:
0010155-0003327 UKO2:
 
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85
Asset
 
Transfer
means, at
 
any particular
 
time, any
 
transfer or
 
transfers by
 
the Issuer
 
or (in
the case
 
of Notes
 
having the
 
benefit of
 
the Guarantee)
 
the Guarantor
 
of all
 
or substantially
all of its and its Subsidiaries' business or
 
operations, taken as a whole, to one or
 
more direct
or indirect wholly-owned Subsidiaries and/or, in the case of the Guarantor, to the Issuer;
Permitted
 
Reorganisation
means
 
any
 
(i)
 
consolidation
 
by
 
the
 
Issuer
 
or
 
(in
 
the
 
case
 
of
Notes having the benefit of
 
the Guarantee) the Guarantor with, or merger
 
of the Issuer or (in
the case
 
of Notes
 
having the
 
benefit of
 
the Guarantee)
 
the Guarantor
 
into, another
 
person,
or (ii) conveyance, transfer
 
or lease by the
 
Issuer or (in the
 
case of Notes having
 
the benefit
of
 
the
 
Guarantee)
 
the
 
Guarantor
 
of
 
all
 
or
 
substantially
 
all
 
of
 
its
 
and
 
its
 
Subsidiaries'
properties and assets, taken as a whole, to any person, in each case
 
where:
(a)
 
the
 
person formed
 
by
 
such
 
consolidation into
 
which the
 
Issuer or
 
the
 
Guarantor,
 
as
the case may be,
 
is merged or the
 
person which acquires by
 
conveyance or transfer,
or which
 
leases, all
 
or substantially all
 
of the
 
properties and
 
assets of the
 
Issuer and
its Subsidiaries or the Guarantor
 
and its Subsidiaries, in each case
 
taken as a whole,
(such
 
person,
 
the
 
Successor)
 
shall
 
be
 
a
 
corporation,
 
partnership
 
or
 
trust,
 
shall
 
be
organised
 
and
 
validly existing
 
under the
 
laws
 
of any
 
jurisdiction
 
and
 
shall expressly
assume,
 
by
 
way
 
of
 
a
 
deed
 
of
 
assumption
 
governed
 
by
 
English
 
law
 
(the
Deed
 
of
Assumption
), all obligations of the
 
Issuer and/or the Guarantor,
 
as applicable, under
the Notes and/or the Guarantee, as applicable; and
(b)
 
the
 
Issuer
 
or
 
the
 
Guarantor,
 
as
 
the
 
case
 
may
 
be,
 
has
 
delivered
 
to
 
the
 
Agent
 
(1)
 
a
certificate signed by one director of
 
the Issuer or,
 
as the case may be,
 
one director of
the Guarantor
 
(in the
 
case of
 
Notes having
 
the benefit
 
of the
 
Guarantee) stating that
such
 
consolidation,
 
merger,
 
conveyance,
 
transfer
 
or
 
lease
 
comply
 
with
 
the
requirements
 
of
 
this
 
definition
 
and
 
that
 
all
 
conditions
 
precedent
 
provided
 
for
 
in
 
this
definition relating to such transaction have been complied with,
 
and (2) legal opinions
from (A)
 
a leading
 
firm of
 
lawyers to
 
the Successor
 
in the
 
country of
 
incorporation of
the Successor, and (B) a leading firm of lawyers to
 
the Successor in England, in each
case
 
to
 
the
 
effect
 
that,
 
as
 
a
 
matter
 
of
 
the
 
relevant
 
law,
 
the
 
Deed
 
of
 
Assumption
constitutes legal, valid and binding
 
obligations of the Successor and
 
is enforceable in
accordance
 
with
 
its
 
terms,
 
such
 
opinions
 
to
 
be
 
available
 
for
 
inspection
 
by
Noteholders and Couponholders at the specified offices of the Agent; and
Subsidiary
means, at
 
any particular
 
time, a
 
company of
 
which the
 
Issuer or
 
(in the
 
case of
Notes
 
having
 
the
 
benefit
 
of
 
the
 
Guarantee)
 
the
 
Guarantor
 
directly
 
or
 
indirectly
 
owns
 
or
controls at least
 
a majority of
 
the outstanding voting
 
stock having power
 
to elect directors
 
of
such company.
9.
 
Replacement of Notes,
 
Coupons and Talons
Should any Note, Coupon or Talon be lost, stolen, mutilated, defaced or destroyed, it may be
replaced at the specified office of the Agent or any Replacement Agent upon payment by the
claimant
 
of
 
such
 
costs
 
and
 
expenses
 
as
 
may
 
be
 
incurred
 
in
 
connection
 
therewith
 
and
 
on
such terms as to
 
evidence and indemnity as the
 
Issuer may reasonably require. Mutilated
 
or
defaced Notes, Coupons or Talons must be surrendered before
 
replacements will be issued.
10.
 
Agent and Paying Agents
The names
 
of the
 
initial Agent
 
and the
 
other initial
 
Paying Agents
 
and their
 
initial specified
offices are set out below.
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The Issuer
 
and the
 
Guarantor (in
 
the case
 
of Notes
 
having the
 
benefit of
 
the Guarantee)
 
is
entitled to
 
vary or
 
terminate the
 
appointment of
 
any Paying
 
Agent and/or
 
appoint additional
or other Paying Agents
 
and/or approve any change in the
 
specified office through which any
Paying Agent acts, provided that:
(i)
 
so
 
long
 
as
 
the
 
Notes
 
are
 
listed
 
on
 
any
 
stock
 
exchange,
 
there
 
will
 
at
 
all
 
times
 
be
 
a
Paying Agent with a specified office
 
in such place as may
 
be required by the rules and
regulations of the relevant stock exchange or other relevant authority;
(ii)
 
there will at all
 
times be a
 
Paying Agent with a
 
specified office outside
 
Norway; and
(iii)
 
there will at all times be
 
an Agent.
In
 
addition,
 
the
 
Issuer
 
and
 
the
 
Guarantor
 
(in
 
the
 
case
 
of
 
Notes
 
having
 
the
 
benefit
 
of
 
the
Guarantee) shall forthwith appoint a Paying Agent
 
having a specified office in
 
New York
 
City
in the
 
circumstances described
 
in the
 
final paragraph
 
of Condition
 
4(d) (
General provisions
applicable
 
to
 
payments
).
 
Notice
 
of
 
any
 
variation,
 
termination,
 
appointment
 
or
 
change
 
in
Paying
 
Agents
 
will
 
be
 
given
 
to
 
the
 
Noteholders
 
promptly
 
by
 
the
 
issuer
 
in
 
accordance
 
with
Condition 12 (
Notices
).
11.
 
Exchange of Talons
On
 
and
 
after
 
the
 
Interest
 
Payment
 
Date,
 
on
 
which
 
the
 
final
 
Coupon
 
comprised
 
in
 
any
Coupon
 
sheet
 
matures,
 
the
 
Talon
 
(if
 
any)
 
forming
 
part
 
of
 
such
 
Coupon
 
sheet
 
may
 
be
surrendered at the specified office
 
of the Agent or
 
any other Paying Agent in
 
exchange for a
further
 
Coupon sheet
 
including (if
 
such further
 
Coupon sheet
 
does not
 
include Coupons
 
to
(and including) the final date for the payment of interest due in respect of the Note to which it
appertains) a further Talon, subject to the provisions of Condition 7 (
Prescription
).
12.
 
Notices
All
 
notices
 
regarding
 
the
 
Notes
 
shall
 
be
 
published
 
in
 
a
 
leading
 
English
 
language
 
daily
newspaper of general circulation in London. It is
 
expected that such publication will be made
in the Financial Times
 
or any other daily
 
newspaper in London. The Issuer
 
shall also ensure
that notices are
 
duly published in a
 
manner which complies with
 
the rules and regulations
 
of
any
 
stock
 
exchange
 
or
 
other
 
relevant
 
authority
 
on
 
which
 
the
 
Notes
 
are
 
for
 
the
 
time
 
being
listed or by
 
which they have
 
been admitted to trading
 
including publication on the
 
website of
the relevant stock
 
exchange or relevant
 
authority if required
 
by those rules.
 
Any such notice
will be
 
deemed to
 
have been
 
given on
 
the date
 
of the
 
first publication
 
or,
 
where required
 
to
be
 
published
 
in
 
both
 
newspapers,
 
on
 
the
 
date
 
of
 
the
 
first
 
publication
 
in
 
both
 
such
newspapers.
Until such
 
time as
 
any definitive
 
Notes are
 
issued, there
 
may (provided
 
that, in
 
the case
 
of
Notes
 
listed
 
on
 
any
 
stock
 
exchange
 
or
 
admitted
 
to
 
trading
 
by
 
another
 
relevant
 
authority,
such
 
stock
 
exchange or
 
relevant
 
authority permits),
 
so
 
long
 
as the
 
global Note(s)
 
is
 
or
 
are
held in its/their entirety
 
on behalf of Euroclear
 
and Clearstream, Luxembourg, be substituted
for such publication in
 
such newspaper(s) or such website
 
the delivery of the
 
relevant notice
to Euroclear and
 
Clearstream, Luxembourg for communication by them
 
to the holders of
 
the
Notes. Any
 
such notice
 
shall be
 
deemed to
 
have been
 
given to
 
the holders
 
of the
 
Notes on
the day on which the said notice was given to Euroclear and Clearstream,
 
Luxembourg.
Notices to
 
be given
 
by any
 
holder of
 
the
 
Notes shall
 
be in
 
writing and
 
given by
 
lodging the
same,
 
together
 
(in
 
the
 
case
 
of
 
any
 
Note
 
in
 
definitive
 
form)
 
with
 
the
 
relative
 
Note
 
or
 
Notes,
with the
 
Agent. Whilst any
 
of the Notes
 
are represented
 
by a global
 
Note, such notice
 
may
0010155-0003327 UKO2:
 
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be
 
given
 
by
 
any
 
holder
 
of
 
a
 
Note
 
to
 
the
 
Agent
 
via
 
Euroclear
 
and/or
 
Clearstream,
Luxembourg,
 
as
 
the
 
case
 
may
 
be,
 
in
 
such
 
manner
 
as
 
the
 
Agent
 
and
 
Euroclear
 
and/or
Clearstream, Luxembourg, as the case may be, may approve for
 
this purpose.
13.
 
Meetings of Noteholders,
 
Modification and
 
Waiver
The
 
Agency
 
Agreement
 
contains
 
provisions
 
for
 
convening
 
meetings
 
(including
 
by
 
way
 
of
conference call or
 
by use of
 
a videoconference platform) of
 
Noteholders to consider matters
affecting
 
their
 
interests,
 
including
 
the
 
sanctioning
 
by
 
Extraordinary
 
Resolution
 
of
 
a
modification of
 
any of
 
these
 
Conditions. Such
 
a meeting
 
may
 
be convened
 
by Noteholders
holding not less than 10 per cent. in nominal principal amount of the Notes for the time being
outstanding. The quorum for
 
any meeting convened to
 
consider an Extraordinary Resolution
will be two or more persons holding or representing a clear majority in nominal amount of the
Notes
 
for
 
the
 
time
 
being
 
outstanding,
 
or
 
at
 
any
 
adjourned
 
meeting
 
one
 
or
 
more
 
persons
being
 
or
 
representing
 
Noteholders
 
whatever
 
the
 
nominal
 
amount
 
of
 
the
 
Notes
 
held
 
or
represented, unless
 
the business
 
of such
 
meeting includes consideration
 
of proposals,
inter
alia
,
 
(i)
 
to
 
modify
 
the
 
maturity
 
of
 
the
 
Notes
 
or
 
the
 
dates
 
on
 
which
 
interest
 
is
 
payable
 
in
respect of
 
the Notes,
 
(ii) to
 
reduce or
 
cancel the
 
principal amount
 
of interest
 
on the
 
Notes,
(iii)
 
to
 
change
 
the
 
currency
 
of
 
payment
 
of
 
the
 
Notes
 
or
 
the
 
Coupons,
 
(iv)
 
to
 
modify
 
the
provisions
 
concerning
 
the
 
quorum
 
required
 
at
 
any
 
meeting
 
of
 
Noteholders
 
or
 
the
 
majority
required to pass an Extraordinary Resolution, or (v) to modify or cancel the obligations of the
Guarantor
 
under
 
the
 
Guarantee,
 
in
 
which
 
case
 
the
 
necessary
 
quorum
 
will
 
be
 
two
 
or
 
more
persons holding
 
or representing not
 
less than
 
75 per
 
cent., or
 
at any
 
adjourned meeting not
less than
 
25 per
 
cent., in
 
principal amount
 
of the
 
Notes for
 
the time
 
being outstanding.
 
The
Agency
 
Agreement
 
provides
 
that
 
(i)
 
a
 
resolution
 
passed
 
at
 
a
 
meeting
 
duly
 
convened
 
and
held in
 
accordance with
 
the Agency
 
Agreement by
 
a majority
 
consisting of
 
not less
 
than 75
per
 
cent.
 
of
 
the
 
votes
 
cast
 
on
 
such
 
resolution,
 
(ii)
 
a
 
resolution
 
in
 
writing
 
signed
 
by
 
or
 
on
behalf
 
of
 
the
 
holders
 
of
 
not
 
less
 
than
 
75
 
per
 
cent.
 
in
 
nominal
 
amount
 
of
 
the
 
Notes
 
for
 
the
time
 
being
 
outstanding
 
or
 
(iii)
 
consent
 
given
 
by
 
way
 
of
 
electronic
 
consents
 
through
 
the
relevant
 
clearing
 
system(s)
 
(in
 
a
 
form
 
satisfactory
 
to
 
the
 
Agent)
 
by
 
or
 
on
 
behalf
 
of
 
the
holders
 
of
 
not
 
less
 
than
 
75
 
per
 
cent.
 
in
 
nominal
 
amount
 
of
 
the
 
Notes
 
for
 
the
 
time
 
being
outstanding,
 
shall,
 
in
 
each
 
case,
 
be
 
effective
 
as
 
an
 
Extraordinary
 
Resolution
 
of
 
the
Noteholders.
 
Any
 
Extraordinary
 
Resolution
 
duly
 
passed
 
shall
 
be
 
binding
 
on
 
Noteholders
(whether
 
or
 
not
 
they
 
were
 
present
 
at
 
any meeting,
 
and
 
whether or
 
not
 
they
 
voted
 
on
 
such
resolution) and on all Couponholders.
The
 
Agent,
 
the
 
Issuer
 
and
 
(in
 
the
 
case
 
of
 
Notes
 
having
 
the
 
benefit
 
of
 
the
 
Guarantee)
 
the
Guarantor may agree, without the consent of the Noteholders or Couponholders,
 
to:
(i)
 
any
 
modification
 
(except
 
as
 
mentioned
 
above)
 
of
 
the
 
Agency
 
Agreement
 
which
 
is,
 
in
the
 
sole
 
opinion
 
of
 
the
 
Issuer
 
and
 
(in
 
the
 
case
 
of
 
Notes
 
having
 
the
 
benefit
 
of
 
the
Guarantee) the Guarantor, not prejudicial to the interests of the Noteholders; or
(ii)
 
any modification
 
of the
 
Notes, the
 
Coupons or
 
the Agency
 
Agreement which
 
is, in
 
the
sole
 
opinion
 
of
 
the
 
Issuer
 
and
 
(in
 
the
 
case
 
of
 
Notes
 
having
 
the
 
benefit
 
of
 
the
Guarantee) the Guarantor,
 
of a
 
formal, minor
 
or technical nature
 
or is
 
made to
 
correct
a manifest error or
 
to comply with mandatory
 
provisions of the law
 
of the jurisdiction in
which the Issuer is incorporated.
Any such
 
modification shall
 
be binding
 
on the
 
Noteholders and
 
the Couponholders
 
and any
such
 
modification
 
shall
 
be
 
notified
 
to
 
the
 
Noteholders
 
in
 
accordance
 
with
 
Condition
 
12
(
Notices
) as soon as practicable thereafter.
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In
 
addition,
 
the
 
Agent
 
shall
 
be
 
obliged
 
to
 
use
 
its
 
reasonable
 
endeavours
 
to
 
effect
 
any
Benchmark
 
Amendments
 
or
 
Benchmark
 
Replacement
 
Confirming
 
Changes
 
in
 
the
circumstances and
 
as otherwise
 
set
 
out
 
in
 
Condition 3(b)(viii)
 
(
Benchmark Discontinuation
)
or Condition
 
(
Benchmark Discontinuation – SOFR
) above (as applicable), without the
consent of the Noteholders or the Couponholders.
14.
 
Substitution
The Issuer,
 
or any
 
previously substituted
 
company,
 
may at
 
any time,
 
without the
 
consent of
the
 
Noteholders
 
or
 
the
 
Couponholders,
 
substitute
 
for
 
itself
 
as
 
principal
 
debtor
 
under
 
the
Notes and
 
the Coupons
 
a company
 
(the
Substitute
) as
 
principal debtor
 
under the
 
Notes or
Coupons in
 
the manner
 
specified in
 
Schedule 6
 
to the
 
Agency Agreement,
 
provided that
 
no
payment
 
in
 
respect
 
of
 
the
 
Notes
 
or
 
the
 
Coupons
 
is
 
at
 
the
 
relevant
 
time
 
overdue.
 
The
substitution
 
shall
 
be
 
made
 
by
 
a
 
deed
 
poll
 
(the
Deed
 
Poll
),
 
to
 
be
 
substantially
 
in
 
the
 
form
exhibited to the Agency Agreement, and may take place only if:
(i)
 
the obligations of the Substitute under
 
the Deed Poll, the Notes
 
and the Coupons shall
be
 
unconditionally and
 
irrevocably guaranteed
 
by
 
Equinor
 
ASA (in
 
such capacity,
 
the
New
 
Guarantor
and such
 
guarantee, the
New Guarantee
) and
 
(in the
 
case of
 
Notes
having the benefit of the Guarantee) the Guarantor, by means of the Deed Poll;
(ii)
 
all action,
 
conditions and
 
things required
 
to be
 
taken, fulfilled
 
and done
 
(including the
obtaining
 
of
 
any
 
necessary
 
consents)
 
to
 
ensure
 
that
 
the
 
Deed
 
Poll,
 
the
 
Notes
 
and
Coupons represent
 
valid, legally
 
binding and
 
enforceable obligations
 
of the
 
Substitute
and
 
in
 
the
 
case
 
of
 
the
 
Deed
 
Poll
 
of
 
the
 
New
 
Guarantor
 
and
 
(in
 
the
 
case
 
of
 
Notes
having the benefit of the Guarantee) the Guarantor have
 
been taken, fulfilled and done
and are in full force and effect;
(iii)
 
the Substitute shall have become party to the Agency Agreement, with any appropriate
consequential amendments, as if it had been an original
 
party to it;
(iv)
 
each
 
stock
 
exchange
 
or
 
listing
 
authority
 
which
 
has
 
the
 
Notes
 
listed
 
on
 
such
 
stock
exchange
 
shall
 
have
 
confirmed
 
that
 
following
 
the
 
proposed
 
substitution
 
of
 
the
Substitute the Notes would continue to be listed on such stock exchange;
(v)
 
legal opinions addressed to the Noteholders shall have been delivered to them (care of
the Agent)
 
from a
 
lawyer or
 
firm of
 
lawyers with
 
a leading
 
securities practice
 
in (i)
 
the
Kingdom
 
of
 
Norway
 
and,
 
if
 
applicable,
 
any
 
Substitute
 
Jurisdiction
 
(as
 
defined
 
in
 
the
final paragraph of
 
this Condition 14 (
Substitution
)) and (ii)
 
England, in each
 
case as to
the
 
fulfilment
 
of
 
the
 
preceding
 
conditions
 
of
 
this
 
Condition
 
14
 
(
Substitution
)
 
and
 
the
other matters specified in the Deed Poll; and
(vi)
 
the
 
Issuer
 
shall
 
have
 
given
 
at
 
least
 
14
 
days'
 
prior
 
notice
 
of
 
such
 
substitution
 
to
 
the
Noteholders,
 
stating
 
that
 
copies,
 
or,
 
pending
 
execution,
 
the
 
agreed
 
text,
 
of
 
all
documents
 
in
 
relation
 
to
 
the
 
substitution which
 
are
 
referred
 
to
 
above,
 
or
 
which
 
might
otherwise
 
reasonably
 
be
 
regarded
 
as
 
material
 
to
 
Noteholders,
 
will
 
be
 
available
 
for
inspection
 
at
 
the
 
specified
 
office
 
of
 
each
 
of
 
the
 
Paying
 
Agents.
 
References
 
in
Condition
 
8
 
(
Events
 
of
 
Default
)
 
to
 
obligations
 
under
 
the
 
Notes
 
shall
 
be
 
deemed
 
to
include obligations under the Deed Poll, and the events listed in
 
Condition 8 (
Events of
Default
) shall be deemed to include the New Guarantee not being (or being claimed by
the
 
New
 
Guarantor
 
not
 
to
 
be)
 
in
 
full
 
force
 
and
 
effect
 
and
 
the
 
provisions of
 
Condition
8(c) to 8(e) (
Events of Default
) inclusive (other than the words "other
 
than in respect of
the
termination
of
the
Guarantee
pursuant
to
Condition
2(c)
(
Termination
of
0010155-0003327 UKO2:
 
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Guarantee
)"
 
in
 
Condition
 
8(e))
 
shall
 
be
 
deemed
 
to
 
apply
 
in
 
addition
 
to
 
the
 
New
Guarantor.
In connection with any proposed substitution pursuant to this
 
Condition 14 (
Substitution
), the
Issuer
 
(or
 
previously
 
substituted
 
company,
 
as
 
the
 
case
 
may
 
be)
 
or
 
Substitute
 
shall
 
not
 
be
required to have regard to, or be in any way liable for,
 
the consequences of such substitution
for
 
individual
 
Noteholders
 
or
 
the
 
Couponholders resulting
 
from
 
their
 
being
 
for
 
any
 
purpose
domiciled
 
or
 
resident
 
in,
 
or
 
otherwise
 
connected
 
with,
 
or
 
subject
 
to
 
the
 
jurisdiction
 
of,
 
any
particular
 
territory.
 
No
 
Noteholder
 
or
 
Couponholder
 
shall,
 
in
 
connection
 
with
 
any
 
such
substitution, be
 
entitled to
 
claim from
 
the Issuer
 
(or
 
previously substituted
 
company,
 
as the
case
 
may
 
be)
 
or
 
Substitute
 
any
 
indemnification
 
or
 
payment
 
in
 
respect
 
of
 
any
 
tax
consequence of
 
any such
 
substitution upon
 
such individual
 
Noteholders or
 
Couponholders,
except
 
to
 
the
 
extent
 
already
 
provided
 
in
 
Condition
 
6
 
(
Taxation
)
 
as
 
modified
 
in
 
accordance
with the following paragraph.
Where
 
a
 
substitution
 
takes
 
place
 
pursuant
 
to
 
this
 
Condition
 
14
 
(
Substitution
)
 
and
 
the
Substitute
 
is
 
subject,
 
by
 
reason
 
of
 
its
 
incorporation
 
or
 
residence
 
for
 
tax
 
purposes,
 
to
 
a
jurisdiction or any political subdivision
 
or any authority thereof
 
or therein having power to
 
tax
(the
Substitute
 
Jurisdiction
)
 
other than
 
the
 
Kingdom
 
of
 
Norway (or,
 
as the
 
case may
 
be,
the
 
jurisdiction
 
of
 
incorporation
 
or
 
residence
 
for
 
tax
 
purposes
 
of
 
the
 
preceding
 
substituted
company) or
 
any political subdivision
 
or any
 
authority thereof
 
or therein having
 
power to
 
tax
(the
Previous
 
Jurisdiction
),
 
references
 
to
 
the
 
Previous
 
Jurisdiction
 
in
 
Condition
 
5(b)
(
Redemption for Tax
 
Reasons
) and Condition
 
6 (
Taxation
) shall, in
 
respect of any
 
payments
to
 
be
 
made
 
by
 
the
 
Substitute
 
(but
 
not
 
in
 
respect
 
of
 
payments
 
to
 
be
 
made
 
by
 
(A)
 
the
 
New
Guarantor under
 
the
 
New Guarantee
 
or (B)
 
(in
 
the
 
case
 
of
 
Notes having
 
the
 
benefit of
 
the
Guarantee)
 
the
 
Guarantor),
 
be
 
deemed
 
to
 
be
 
replaced
 
by
 
references
 
to
 
the
 
Substitute
Jurisdiction,
 
and
 
Conditions
 
5(b)
 
(
Redemption
 
for
 
Tax
 
Reasons
)
 
and
 
6
 
(
Taxation
)
 
shall
 
be
deemed to be modified accordingly when the substitution takes place.
15.
 
Further Issues
The
 
Issuer
 
shall
 
be
 
at
 
liberty
 
from
 
time
 
to
 
time
 
without
 
the
 
consent
 
of
 
the
 
Noteholders
 
or
Couponholders to
 
create and
 
issue further
 
notes having
 
terms
 
and conditions
 
the
 
same as
the
 
Notes or
 
the
 
same in
 
all respects
 
save for
 
the amount
 
and date
 
of the
 
first payment
 
of
interest thereon and so that the same shall be consolidated and form a single Series with the
outstanding Notes.
16.
 
Contracts (Rights of
 
Third Parties) Act 1999
A person
 
who is
 
not a Noteholder
 
has no right
 
under the Contracts
 
(Rights of
 
Third Parties)
Act
 
1999
 
(the
 
Act)
 
to
 
enforce
 
any
 
term
 
of
 
the
 
Notes,
 
but
 
this
 
does
 
not
 
affect
 
any
 
right
 
or
remedy of a third party which exists or is available apart from
 
the Act.
17.
 
Governing Law and Submission
 
to Jurisdiction
(a)
 
The
 
Agency
 
Agreement,
 
the
 
Guarantee,
 
the
 
Notes
 
and
 
the
 
Coupons
 
and
 
any
 
non-
contractual obligations arising
 
out of
 
or in
 
connection with the
 
Agency Agreement, the
Guarantee,
 
the
 
Notes
 
and
 
the
 
Coupons
 
are
 
governed
 
by,
 
and
 
shall
 
be
 
construed
 
in
accordance with, English law.
(b)
 
Subject to
 
paragraph
, the
 
courts of
 
England are to
 
have jurisdiction to
 
settle
any
 
disputes
 
(including
 
a
 
dispute
 
relating
 
to
 
any
 
non-contractual
 
obligations)
 
which
may
 
arise out
 
of
 
or in
 
connection with
 
the Guarantee,
 
the
 
Notes or
 
the Coupons
 
and
accordingly
 
any
 
legal
 
action
 
or
 
proceedings
 
arising
 
out
 
of
 
or
 
in
 
connection
 
with
 
the
0010155-0003327 UKO2:
 
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Guarantee, the
 
Notes or
 
the Coupons
 
(
Proceedings
) may
 
be brought
 
in such
 
courts.
Each
 
of
 
the
 
Issuer
 
and
 
the
 
Guarantor
 
irrevocably
 
submits
 
to
 
the
 
jurisdiction
 
of
 
such
courts
 
and
 
waives
 
any
 
objection
 
to
 
Proceedings
 
in
 
any
 
such
 
courts
 
whether
 
on
 
the
ground
 
of
 
venue
 
or
 
on
 
the
 
ground
 
that
 
the
 
Proceedings
 
have
 
been
 
brought
 
in
 
an
inconvenient forum.
(c)
 
This
 
paragraph
 
is
 
for
 
the
 
benefit
 
of
 
each
 
of
 
the
 
Noteholders
 
and
 
Couponholders
only.
 
To
 
the
 
extent
 
permitted
 
by
 
applicable
 
law,
 
each
 
of
 
the
 
Noteholders
 
and
Couponholders may
 
take Proceedings
 
against the
 
Issuer and/or
 
the Guarantor
 
in any
other
 
court
 
of
 
competent
 
jurisdiction
 
and
 
concurrent
 
Proceedings
 
in
 
any
 
number
 
of
jurisdictions.
(d)
 
Each
 
of
 
the
 
Issuer
 
and
 
the
 
Guarantor
 
irrevocably
 
appoints
 
Equinor
 
UK
 
Limited
 
at
 
its
registered
 
office
 
in
 
England
 
for
 
the
 
time
 
being
 
at
 
One
 
Kingdom
 
Street,
 
Paddington
Central, London W2
 
6BD to receive
 
service of process
 
in any Proceedings
 
in England
based on any of
 
the Notes or Coupons. If
 
for any reason the
 
Issuer or Guarantor does
not have
 
such an agent
 
in England, it
 
will promptly appoint
 
a substitute process
 
agent
and notify the Noteholders
 
of such appointment. Nothing herein
 
shall affect the right
 
to
serve process in any other manner permitted by law.
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AGENT
The Bank of New
 
York Mellon, London
Branch One Canada Square
London E14
 
5AL
United Kingdom
PAYING
 
AGENT
The Bank of New York Mellon SA/NV, Luxembourg Branch
Vertigo Building - Polaris
2-4 rue,
 
Eugène
Ruppert L-2453
Luxembourg
and/or such other or further Agent and other or further Paying
 
Agents and/or specified offices as
may from time to time be duly appointed by the Issuer and notice of
 
which has been given to the
Noteholders.
0010155-0003327 UKO2:
 
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SCHEDULE 2
FORMS OF GLOBAL AND
 
DEFINITIVE NOTES, COUPONS
 
AND TALONS
PART 1
FORM OF TEMPORARY GLOBAL NOTE
EQUINOR ASA
TEMPORARY GLOBAL NOTE
Unconditionally and (subject to
 
Condition 2(c)) irrevocably
guaranteed by EQUINOR ENERGY AS
This
 
Global
 
Note is
 
a Temporary
 
Global
 
Note in
 
respect of
 
a duly
 
authorised issue
 
of
 
Notes (the
Notes
) of Equinor ASA (the
Issuer
) described, and having the provisions specified, in Part A of the
attached Final Terms
 
(the
Final Terms
).
 
References in this Global Note to
 
the Conditions shall be
to
 
the
 
Terms
 
and
 
Conditions of
 
the
 
Notes other
 
than
 
VPS
 
Notes
 
as set
 
out
 
in
 
Schedule 1
 
to
 
the
Agency Agreement (as defined
 
below) as completed by
 
the information set out
 
in the Final Terms,
but in
 
the event
 
of any
 
conflict between the
 
provisions of (a)
 
that Schedule or
 
(b) this
 
Global Note
and the information set out in the Final Terms, the Final Terms
 
will prevail.
Words and
 
expressions defined or
 
set out in
 
the Conditions and/or
 
the Final Terms
 
shall have the
same meaning when used in this Global Note.
This
 
Global
 
Note
 
is
 
issued
 
subject
 
to,
 
and
 
with
 
the
 
benefit
 
of,
 
the
 
Conditions
 
and
 
an
 
Agency
Agreement (the
Agency
 
Agreement
,
 
which expression
 
shall be
 
construed as
 
a reference
 
to that
agreement as
 
the
 
same may
 
be amended,
 
supplemented, novated
 
or restated
 
from time
 
to time)
dated
 
13
 
May
 
2020
 
and
 
made
 
between
 
the
 
Issuer,
 
Equinor
 
Energy
 
AS
 
as
 
guarantor
 
(the
Guarantor
), The Bank of New York Mellon (the
Agent
) and the other agents named in it.
For value received the Issuer, subject to and
 
in accordance with the Conditions, promises to pay to
the bearer
 
of this
 
Global Note
 
on the
 
Maturity Date
 
and/or on
 
such earlier
 
date(s) as
 
all or
 
any of
the Notes represented by this
 
Global Note may become due and
 
repayable in accordance with the
Conditions, the
 
amount payable
 
under the
 
Conditions in
 
respect of
 
the Notes
 
represented by
 
this
Global
 
Note
 
on
 
each
 
such
 
date
 
and
 
to
 
pay
 
interest
 
(if
 
any)
 
on
 
the
 
nominal amount
 
of
 
the
 
Notes
from
 
time
 
to
 
time
 
represented
 
by
 
this
 
Global
 
Note
 
calculated
 
and
 
payable
 
as
 
provided
 
in
 
the
Conditions
 
together
 
with
 
any
 
other
 
sums
 
payable under
 
the
 
Conditions,
 
upon
 
(if
 
the
 
Final
 
Terms
indicates
 
that
 
this
 
Global
 
Note
 
is
 
not
 
intended
 
to
 
be
 
a
 
New
 
Global
 
Note)
 
presentation
 
and,
 
at
maturity,
 
surrender
 
of
 
this Global
 
Note to
 
or
 
to
 
the
 
order
 
of
 
the
 
Agent or
 
any
 
of
 
the
 
other
 
paying
agents located
 
outside the
 
United States
 
(except as
 
provided in
 
the Conditions)
 
from time
 
to time
appointed by the Issuer
 
and the Guarantor
 
in respect of the
 
Notes, but in each
 
case subject to the
requirements as to certification provided below.
If the Final Terms
 
indicates that this Global Note is intended to
 
be a New
 
Global Note, the nominal
amount of Notes represented by this Global Note shall be the aggregate nominal amount from time
to
 
time
 
entered
 
in
 
the
 
records
 
of
 
both
 
Euroclear
 
Bank
 
SA/NV
 
and
 
Clearstream
 
Banking
 
S.A.
(together,
 
the
relevant Clearing
 
Systems
).
 
The records
 
of the
 
relevant Clearing
 
Systems (which
expression in this
 
Global Note means
 
the records that
 
each relevant Clearing
 
System holds for
 
its
customers which
 
reflect the
 
amount of
 
such customer's
 
interest in
 
the
 
Notes) shall
 
be conclusive
evidence of the nominal amount of Notes represented by this Global Note and, for
 
these purposes,
a
 
statement
 
issued
 
by
 
a
 
relevant
 
Clearing
 
System
 
stating
 
the
 
nominal
 
amount
 
of
 
Notes
represented
 
by
 
this
 
Global
 
Note
 
at
 
any
 
time
 
(which
 
statement
 
shall
 
be
 
made
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available to
 
the
 
bearer
 
upon request)
 
shall be
 
conclusive evidence
 
of
 
the records
 
of the
 
relevant
Clearing System at that time.
If
 
the
 
Final
 
Terms
 
indicates
 
that
 
this
 
Global
 
Note
 
is
 
not
 
intended
 
to
 
be
 
a
 
New
 
Global
 
Note,
 
the
nominal
 
amount
 
of
 
the
 
Notes
 
represented
 
by
 
this
 
Global
 
Note
 
shall
 
be
 
the
 
amount
 
stated
 
in
 
the
Final Terms
 
or, if
 
lower, the
 
nominal amount most recently
 
entered by or on
 
behalf of the
 
Issuer in
the relevant column in Part 2 or 3 of Schedule One or in Schedule
 
Two.
On any
 
redemption or payment
 
of interest being
 
made in respect
 
of, or
 
purchase and cancellation
of, any of the Notes represented by this Global Note the Issuer shall
 
procure that:
(a)
 
if
 
the
 
Final
 
Terms
 
indicates
 
that
 
this
 
Global
 
Note
 
is
 
intended
 
to
 
be
 
a
 
New
 
Global
 
Note,
details
 
of
 
such
 
redemption,
 
payment
 
or
 
purchase
 
and
 
cancellation
 
(as
 
the
 
case
 
may
 
be)
shall
 
be
 
entered
 
pro
 
rata
 
in
 
the
 
records
 
of
 
the
 
relevant
 
Clearing
 
Systems
 
and,
 
upon
 
any
such
 
entry
 
being
 
made,
 
the
 
nominal
 
amount
 
of
 
the
 
Notes
 
recorded
 
in
 
the
 
records
 
of
 
the
relevant
 
Clearing
 
Systems
 
and
 
represented
 
by
 
this
 
Global
 
Note
 
shall
 
be
 
reduced
 
by
 
the
aggregate nominal amount of the Notes so redeemed or purchased
 
and cancelled; or
(b)
 
if the
 
Final Terms
 
indicates that this
 
Global Note
 
is not
 
intended to
 
be a
 
New Global
 
Note,
details
 
of
 
such
 
redemption,
 
payment
 
or
 
purchase
 
and
 
cancellation
 
(as
 
the
 
case
 
may
 
be)
shall be
 
entered by
 
or
 
on behalf
 
of the
 
Issuer in
 
Schedule One
 
and the
 
relevant space
 
in
Schedule One
 
recording any
 
such redemption,
 
payment or
 
purchase and
 
cancellation (as
the case may be) shall be signed
 
by or on behalf of the Issuer.
 
Upon any such redemption,
purchase
 
and
 
cancellation,
 
the
 
nominal
 
amount
 
of
 
the
 
Notes
 
represented
 
by
 
this
 
Global
Note shall be
 
reduced by the
 
nominal amount of the
 
Notes so redeemed or
 
purchased and
cancelled.
Payments
 
due
 
in
 
respect
 
of
 
Notes
 
for
 
the
 
time
 
being
 
represented
 
by
 
this
 
Global
 
Note
 
shall
 
be
made
 
to
 
the
 
bearer
 
of
 
this
 
Global
 
Note
 
and
 
each
 
payment
 
so
 
made
 
will
 
discharge
 
the
 
Issuer's
obligations
 
in
 
respect
 
thereof.
 
Any
 
failure
 
to
 
make
 
the
 
entries
 
referred
 
to
 
above
 
shall
 
not
 
affect
such discharge.
Prior to
 
the Exchange
 
Date (as
 
defined below),
 
all payments
 
(if any)
 
on this
 
Global Note
 
will only
be
 
made
 
to
 
the
 
bearer
 
hereof
 
to
 
the
 
extent
 
that
 
there
 
is
 
presented
 
to
 
the
 
Agent
 
by
 
a
 
relevant
Clearing System a certificate to the effect that it has received from or in respect of a person entitled
to
 
a
 
particular
 
nominal
 
amount
 
of
 
the
 
Notes
 
(as
 
shown
 
by
 
its
 
records)
 
a
 
certificate
 
of
 
non-US
beneficial ownership in the form required by it.
 
The bearer of this Global Note will not be entitled to
receive any
 
payment of
 
interest
 
due on
 
or
 
after the
 
Exchange Date
 
unless upon
 
due certification
exchange of this Global Note is improperly
 
withheld or refused.
On or
 
after the
 
date (the
Exchange Date
) which
 
is 40
 
days after
 
the Issue
 
Date this
 
Global Note
may be exchanged in whole or in part (free of charge) for, as specified in the Final Terms, either:
(a)
 
security printed Definitive Notes
 
and (if applicable) Coupons
 
and Talons
 
in the form
 
set out
in
 
Part
 
3,
 
Part
 
4
 
and
 
Part
 
5 respectively
 
of
 
Schedule 2
 
to
 
the
 
Agency Agreement
 
(on
 
the
basis
 
that
 
all
 
the
 
appropriate
 
details
 
have
 
been
 
included
 
on
 
the
 
face
 
of
 
such
 
Definitive
Notes
 
and
 
(if
 
applicable)
 
Coupons
 
and
 
Talons
 
and
 
the
 
Final
 
Terms
 
(or
 
the
 
relevant
provisions
 
of
 
the
 
Final
 
Terms)
 
have
 
been
 
endorsed
 
on
 
or
 
attached
 
to
 
such
 
Definitive
Notes); or
(b)
 
either,
 
(i) if
 
the Final
 
Terms
 
indicates that
 
this Global
 
Note is
 
intended to
 
be a
 
New Global
Note,
 
interests
 
recorded
 
in
 
the
 
records
 
of
 
the
 
relevant
 
Clearing
 
Systems
 
in
 
a
 
Permanent
Global Note or,
 
(ii) if the
 
Final Terms
 
indicates that this Global
 
Note is not
 
intended to be
 
a
New Global
 
Note, a
 
Permanent Global
 
Note, which,
 
in either
 
case, is
 
in or
 
substantially in
the form
 
set out
 
in Part
 
2 of
 
Schedule 6
 
to the
 
Agency Agreement
 
(together with
 
the Final
Terms
 
attached to it),
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in each
 
case upon
 
notice being
 
given by
 
a relevant
 
Clearing System
 
acting on
 
the instructions
 
of
any holder of an interest in this Global Note.
If
 
Definitive
 
Notes
 
and
 
(if
 
applicable)
 
Coupons
 
and/or
 
Talons
 
have
 
already
 
been
 
issued
 
in
exchange for all the
 
Notes represented for the time
 
being by the Permanent Global
 
Note, then this
Global
 
Note
 
may
 
only
 
thereafter
 
be
 
exchanged
 
for
 
Definitive
 
Notes
 
and
 
(if
 
applicable)
 
Coupons
and/or Talons
 
in accordance with the terms of this Global Note.
This
 
Global
 
Note may
 
be
 
exchanged by
 
the
 
bearer
 
hereof
 
on
 
any
 
day
 
(other
 
than
 
a
 
Saturday or
Sunday) on
 
which banks
 
are open
 
for general
 
business in
 
London.
 
The Issuer
 
shall procure
 
that,
as appropriate, (i)
 
the Definitive Notes
 
or (as the
 
case may be)
 
the Permanent Global
 
Note issued
and delivered,
 
or (ii)
 
the interests
 
in the
 
Permanent Global
 
Note (where
 
the Final
 
Terms
 
indicates
that this
 
Global Note
 
is intended to
 
be a
 
New Global Note)
 
shall be
 
recorded in
 
the records
 
of the
relevant
 
Clearing
 
System,
 
in
 
each
 
case
 
in
 
exchange
 
for
 
only
 
that
 
portion
 
of
 
this
 
Global
 
Note
 
in
respect
 
of
 
which
 
there
 
shall
 
have
 
been
 
presented
 
to
 
the
 
Agent
 
by
 
a
 
relevant
 
Clearing
 
System
 
a
certificate
 
to
 
the
 
effect
 
that
 
it
 
has
 
received
 
from
 
or
 
in
 
respect
 
of
 
a
 
person
 
entitled
 
to
 
a
 
beneficial
interest in
 
a particular
 
nominal amount
 
of the
 
Notes (as
 
shown by
 
its records)
 
a certificate
 
of non-
US
 
beneficial
 
ownership
 
from
 
such
 
person
 
in
 
the
 
form
 
required
 
by
 
it.
 
The
 
aggregate
 
nominal
amount
 
of
 
Definitive Notes
 
or
 
interests in
 
a
 
Permanent Global
 
Note issued
 
upon
 
an exchange
 
of
this Global Note will, subject to the terms
 
hereof, be equal to the aggregate nominal amount of
 
this
Global Note submitted by the bearer for exchange.
On an exchange of the whole of this Global Note, this Global Note shall be surrendered to or to the
order of the Agent.
 
On an exchange of part only of this Global Note, the Issuer
 
shall procure that:
(a)
 
if
 
the
 
Final
 
Terms
 
indicates
 
that
 
this
 
Global
 
Note
 
is
 
intended
 
to
 
be
 
a
 
New
 
Global
 
Note,
details
 
of such
 
exchange shall
 
be entered
 
pro rata
 
in the
 
records of
 
the
 
relevant Clearing
Systems; or
(b)
 
if the
 
Final Terms
 
indicates that this
 
Global Note
 
is not
 
intended to
 
be a
 
New Global
 
Note,
details
 
of
 
such
 
exchange
 
shall
 
be
 
entered
 
by
 
or
 
on
 
behalf
 
of
 
the
 
Issuer
 
in
 
Schedule
 
Two
and the relevant space
 
in Schedule Two
 
recording such exchange shall be
 
signed by or on
behalf
 
of
 
the
 
Issuer,
 
whereupon
 
the
 
nominal
 
amount
 
of
 
this
 
Global
 
Note
 
and
 
the
 
Notes
represented
 
by
 
this
 
Global
 
Note
 
shall
 
be
 
reduced
 
by
 
the
 
nominal
 
amount
 
so
 
exchanged.
On
 
any
 
exchange
 
of
 
this
 
Global
 
Note
 
for
 
a
 
Permanent
 
Global
 
Note,
 
details
 
of
 
such
exchange
 
shall
 
also
 
be
 
entered
 
by
 
or
 
on
 
behalf
 
of
 
the
 
Issuer
 
in
 
Schedule
 
Two
 
to
 
the
Permanent Global
 
Note and
 
the relevant
 
space in
 
Schedule Two
 
to the
 
Permanent Global
Note recording such exchange shall be signed by or on behalf of the
 
Issuer.
Until
 
the
 
exchange
 
of
 
the
 
whole
 
of
 
this
 
Global
 
Note,
 
the
 
bearer
 
of
 
this
 
Global
 
Note
 
shall
 
in
 
all
respects (except
 
as otherwise
 
provided in
 
this Global
 
Note) be
 
entitled to
 
the same
 
benefits as
 
if
he were the bearer of Definitive Notes and the
 
relative Coupons and/or Talons
 
(if any) represented
by
 
this
 
Global
 
Note.
 
Accordingly,
 
except
 
as
 
ordered
 
by
 
a
 
court
 
of
 
competent
 
jurisdiction
 
or
 
as
required by law or
 
applicable regulation, the Issuer and
 
any Paying Agent may deem
 
and treat the
holder of this Global Note as the
 
absolute owner of this Global Note for all purposes.
In the event
 
that this Global
 
Note (or any
 
part of it)
 
has become due
 
and repayable in
 
accordance
with the
 
Conditions or
 
that the
 
Maturity Date
 
(if any)
 
has occurred
 
and, in
 
either case,
 
payment in
full of
 
the amount
 
due has
 
not been
 
made to
 
the bearer
 
in accordance
 
with the
 
provisions set
 
out
above,
 
then
 
from
 
8.00
 
p.m.
 
(London
 
time)
 
on
 
such
 
day
 
each
 
Noteholder
 
will
 
become
 
entitled
 
to
proceed directly against the Issuer on, and subject to, the terms of the Deed of Covenant executed
by
 
the
 
Issuer
 
on
 
13
 
May
 
2020
 
(as
 
amended,
 
supplemented,
 
novated
 
and/or
 
restated
 
as
 
at
 
the
Issue
 
Date)
 
in
 
respect
 
of
 
the
 
Notes
 
and
 
the
 
bearer
 
will
 
have
 
no
 
further
 
rights
 
under
 
this
 
Global
Note (but without
 
prejudice to the rights
 
which the bearer or
 
any other person may
 
have under the
Deed of Covenant).
 
 
 
 
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No
 
rights
 
are
 
conferred on
 
any
 
person
 
under the
 
Contracts (Rights
 
of
 
Third
 
Parties)
 
Act
 
1999 to
enforce
 
any
 
term
 
of
 
this
 
Global
 
Note,
 
but
 
this
 
does
 
not
 
affect
 
any
 
right
 
or
 
remedy
 
of
 
any
 
person
which exists or is available apart from that Act.
If
 
any
 
provision
 
in
 
or
 
obligation
 
under
 
this
 
Global
 
Note
 
is
 
or
 
becomes
 
invalid,
 
illegal
 
or
unenforceable in
 
any respect
 
under the
 
law of
 
any jurisdiction,
 
that will
 
not
 
affect or
 
impair (i)
 
the
validity,
 
legality
 
or
 
enforceability
 
under
 
the
 
law
 
of
 
that
 
jurisdiction
 
of
 
any
 
other
 
provision
 
in
 
or
obligation under this Global Note, and
 
(ii) the validity,
 
legality or enforceability under the law of
 
any
other jurisdiction of that or any
 
other provision in or obligation under this Global Note.
This
 
Global
 
Note
 
and
 
any
 
non-contractual
 
obligations
 
arising
 
out
 
of
 
or
 
in
 
connection
 
with
 
it
 
are
governed by, and shall be construed in accordance with, English law.
This
 
Global
 
Note
 
shall
 
not
 
be
 
valid
 
unless
 
authenticated
 
by
 
the
 
Agent
 
and,
 
if
 
the
 
Final
 
Terms
indicates that this Global Note is intended to be a NGN (i) which is intended to be held in
 
a manner
which
 
would
 
allow
 
Eurosystem
 
eligibility
 
or
 
(ii)
 
in
 
respect
 
of
 
which
 
effectuation
 
is
 
applicable,
effectuated by the entity
 
appointed as common safe-keeper by the relevant Clearing Systems.
IN WITNESS
whereof the Issuer has caused
 
this Global Note to be duly
 
executed on its behalf.
EQUINOR ASA
By:
Authenticated without
 
recourse,
warranty or liability by
THE
 
BANK
 
OF
 
NEW
 
YORK
MELLON
By:
Effectuated without
recourse, warranty or
liability by
...................................................
as common safekeeper
By:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
0010155-0003327 UKO2:
 
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96
SCHEDULE ONE TO
 
THE TEMPORARY GLOBAL NOTE
1
PART 1
INTEREST PAYMENTS
Date made
Total
 
amount of interest
payable
Amount of interest paid
Confirmation of payment
on
behalf of the Issuer
1
 
Schedule One should
 
only be completed where
 
the Final Terms indicates that this Global
 
Note is not intended
 
to be a New
Global Note.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
*
See the most recent entry
 
in Part 2 or 3 of
 
Schedule One or in
 
Schedule Two in order to determine
this amount.
0010155-0003327 UKO2:
 
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97
PART 2
REDEMPTIONS
Date made
Total
 
amount
of principal
payable
Amount of
 
principal
paid
Remaining nominal
amount of
 
this
Global Note
following such
redemption
*
Confirmation of
redemption on
behalf of the Issuer
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
*
See the most recent entry
 
in Part 2 or 3 of
 
Schedule One or in
 
Schedule Two in order to determine
this amount.
0010155-0003327 UKO2:
 
2004375908.9
98
PART 3
PURCHASES AND CANCELLATIONS
Date made
Part of
 
nominal
amount of this Global
Note
purchased and cancelled
Remaining nominal
amount of this
 
Global Note
following such purchase
and
cancellation
*
Confirmation of
purchase and
cancellation on
 
behalf
of the Issuer
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
0010155-0003327 UKO2:
 
2004375908.9
99
SCHEDULE TWO TO THE
 
TEMPORARY GLOBAL NOTE
2
EXCHANGES
FOR DEFINITIVE NOTES
 
OR PERMANENT GLOBAL
 
NOTE
The following exchanges of a part of this Global Note
 
for Definitive Notes or a Permanent Global
Note have been made:
Date made
Nominal amount of this
Global Note
 
exchanged for
Definitive Notes or a
Permanent Global Note
Remaining nominal
amount of
 
this Global
Note
following such exchange
*
Notation made
 
on
behalf of the Issuer
2
 
Schedule Two should only be
 
completed where the
 
Final Terms indicates that this Global Note
 
is not intended to
 
be a New
Global Note.
*
 
See the most recent entry
 
in Part 2 or 3 of
 
Schedule One or in
 
Schedule Two in order to determine
 
this amount.
0010155-0003327 UKO2:
 
2004375908.9
100
PART 2
FORM OF PERMANENT
 
GLOBAL NOTE
ANY
 
UNITED
 
STATES
 
PERSON
 
WHO
 
HOLDS
 
THIS
 
OBLIGATION
 
WILL
 
BE
 
SUBJECT
 
TO
LIMITATIONS
 
UNDER
 
THE
 
UNITED
 
STATES
 
INCOME
 
TAX
 
LAWS
 
INCLUDING
 
THE
LIMITATIONS
 
PROVIDED
 
IN
 
SECTIONS
 
165(J)
 
AND
 
1287(A)
 
OF
 
THE
 
INTERNAL
 
REVENUE
CODE.
EQUINOR ASA
PERMANENT GLOBAL
 
NOTE
Unconditionally and (subject to
 
Condition 2(c)) irrevocably
guaranteed by EQUINOR ENERGY AS
This Global
 
Note is
 
a Permanent
 
Global Note
 
in respect
 
of
 
a duly
 
authorised issue
 
of
 
Notes (the
Notes
) of Equinor ASA (the
Issuer
) described, and having the provisions specified, in Part A of the
attached Final Terms
 
(the
Final Terms
).
 
References in this Global Note to
 
the Conditions shall be
to
 
the
 
Terms
 
and
 
Conditions of
 
the
 
Notes other
 
than
 
VPS
 
Notes
 
as set
 
out
 
in
 
Schedule 1
 
to
 
the
Agency Agreement (as defined
 
below) as completed by
 
the information set out
 
in the Final Terms,
but in
 
the event
 
of any
 
conflict between the
 
provisions of (a)
 
that Schedule or
 
(b) this
 
Global Note
and the information set out in the Final Terms, the Final Terms
 
will prevail.
Words and
 
expressions defined or
 
set out in
 
the Conditions and/or
 
the Final Terms
 
shall have the
same meaning when used in this Global Note.
This
 
Global
 
Note
 
is
 
issued
 
subject
 
to,
 
and
 
with
 
the
 
benefit
 
of,
 
the
 
Conditions
 
and
 
an
 
Agency
Agreement (the
Agency
 
Agreement
,
 
which expression
 
shall be
 
construed as
 
a reference
 
to that
agreement as
 
the
 
same may
 
be amended,
 
supplemented, novated
 
or restated
 
from time
 
to time)
dated 13 May 2020 and
 
made between the Issuer,
 
Equinor Energy AS (the
Guarantor
), The Bank
of New York Mellon (the
Agent
) and the other agents named in it.
For value received the Issuer, subject to and
 
in accordance with the Conditions, promises to pay to
the bearer
 
of this
 
Global Note
 
on the
 
Maturity Date
 
and/or on
 
such earlier
 
date(s) as
 
all or
 
any of
the Notes represented by this
 
Global Note may become due and
 
repayable in accordance with the
Conditions, the
 
amount payable
 
under the
 
Conditions in
 
respect of
 
the Notes
 
represented by
 
this
Global
 
Note
 
on
 
each
 
such
 
date
 
and
 
to
 
pay
 
interest
 
(if
 
any)
 
on
 
the
 
nominal amount
 
of
 
the
 
Notes
from
 
time
 
to
 
time
 
represented
 
by
 
this
 
Global
 
Note
 
calculated
 
and
 
payable
 
as
 
provided
 
in
 
the
Conditions
 
together
 
with
 
any
 
other
 
sums
 
payable under
 
the
 
Conditions,
 
upon
 
(if
 
the
 
Final
 
Terms
indicates
 
that
 
this
 
Global
 
Note
 
is
 
not
 
intended
 
to
 
be
 
a
 
New
 
Global
 
Note)
 
presentation
 
and,
 
at
maturity,
 
surrender
 
of
 
this Global
 
Note to
 
or
 
to
 
the
 
order
 
of
 
the
 
Agent or
 
any
 
of
 
the
 
other
 
paying
agents located
 
outside the
 
United States
 
(except as
 
provided in
 
the Conditions)
 
from time
 
to time
appointed by the Issuer and the Guarantor in respect of the Notes.
If the Final Terms
 
indicates that this Global Note is intended
 
to be a New Global Note,
 
the nominal
amount of Notes
 
represented by this Global
 
Note shall be
 
the aggregate amount from
 
time to time
entered in the records
 
of both Euroclear Bank SA/NV and
 
Clearstream Banking S.A. (together,
 
the
relevant
 
Clearing
 
Systems
).
 
The records
 
of the
 
relevant Clearing
 
Systems (which
 
expression in
this
 
Global
 
Note
 
means
 
the
 
records
 
that
 
each
 
relevant
 
Clearing
 
System
 
holds
 
for
 
its
 
customers
which reflect
 
the amount of
 
such customer's
 
interest in the
 
Notes) shall be
 
conclusive evidence of
the nominal amount of Notes represented by this Global Note and, for these purposes, a statement
issued
 
by
 
a
 
relevant
 
Clearing
 
System
 
stating
 
the
 
nominal
 
amount
 
of
 
Notes
 
represented
 
by
 
this
Global
 
Note
 
at
 
any
 
time
 
(which
 
statement
 
shall
 
be
 
made
0010155-0003327 UKO2:
 
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available to
 
the
 
bearer
 
upon request)
 
shall be
 
conclusive evidence
 
of
 
the
 
records
 
of the
 
relevant
Clearing System at that time.
If
 
the
 
Final
 
Terms
 
indicates
 
that
 
this
 
Global
 
Note
 
is
 
not
 
intended
 
to
 
be
 
a
 
New
 
Global
 
Note,
 
the
nominal
 
amount
 
of
 
the
 
Notes
 
represented
 
by
 
this
 
Global
 
Note
 
shall
 
be
 
the
 
aggregate
 
nominal
amount stated
 
in the
 
Final Terms
 
or,
 
if lower,
 
the nominal
 
amount most
 
recently entered
 
by or
 
on
behalf of the Issuer in the relevant column in Part 2 or 3 of Schedule
 
One or in Schedule Two.
On any
 
redemption or payment
 
of interest being
 
made in
 
respect of, or
 
purchase and cancellation
of, any of the Notes represented by this Global Note the Issuer shall
 
procure that:
(i)
 
if
 
the
 
Final
 
Terms
 
indicates
 
that
 
this
 
Global
 
Note
 
is
 
intended
 
to
 
be
 
a
 
New
 
Global
 
Note,
details
 
of
 
such
 
redemption,
 
payment
 
or
 
purchase
 
and
 
cancellation
 
(as
 
the
 
case
 
may
 
be)
shall
 
be
 
entered
 
pro
 
rata
 
in
 
the
 
records
 
of
 
the
 
relevant
 
Clearing
 
Systems
 
and,
 
upon
 
any
such
 
entry
 
being
 
made,
 
the
 
nominal
 
amount
 
of
 
the
 
Notes
 
recorded
 
in
 
the
 
records
 
of
 
the
relevant
 
Clearing
 
Systems
 
and
 
represented
 
by
 
this
 
Global
 
Note
 
shall
 
be
 
reduced
 
by
 
the
aggregate nominal amount of the Notes so redeemed or purchased
 
and cancelled; or
(ii)
 
if the
 
Final Terms
 
indicates that this
 
Global Note
 
is not
 
intended to
 
be a
 
New Global
 
Note,
details
 
of
 
such
 
redemption,
 
payment
 
or
 
purchase
 
and
 
cancellation
 
(as
 
the
 
case
 
may
 
be)
shall be
 
entered by
 
or
 
on behalf
 
of the
 
Issuer in
 
Schedule One
 
and the
 
relevant space
 
in
Schedule One
 
recording any
 
such redemption,
 
payment or
 
purchase and
 
cancellation (as
the case may
 
be) shall be
 
signed by or
 
on behalf of the
 
Issuer.
 
Upon any such redemption
or purchase
 
and cancellation, the
 
nominal amount
 
of the
 
Notes represented
 
by this
 
Global
Note shall be
 
reduced by the
 
nominal amount of the
 
Notes so redeemed or
 
purchased and
cancelled.
Payments
 
due
 
in
 
respect
 
of
 
Notes
 
for
 
the
 
time
 
being
 
represented
 
by
 
this
 
Global
 
Note
 
shall
 
be
made
 
to
 
the
 
bearer
 
of
 
this
 
Global
 
Note
 
and
 
each
 
payment
 
so
 
made
 
will
 
discharge
 
the
 
Issuer's
obligations
 
in
 
respect
 
thereof.
 
Any
 
failure
 
to
 
make
 
the
 
entries
 
referred
 
to
 
above
 
shall
 
not
 
affect
such discharge.
Where the Notes
 
have initially been represented
 
by one or
 
more Temporary
 
Global Notes, on
 
any
exchange of any such Temporary
 
Global Note for this Global Note or any part of
 
it, the Issuer shall
procure that:
(i)
 
if
 
the
 
Final
 
Terms
 
indicates
 
that
 
this
 
Global
 
Note
 
is
 
intended
 
to
 
be
 
a
 
New
 
Global
 
Note,
details of
 
such exchange shall
 
be entered
 
in the
 
records of
 
the relevant Clearing
 
Systems;
or
(ii)
 
if the
 
Final Terms
 
indicates that this
 
Global Note
 
is not
 
intended to
 
be a
 
New Global
 
Note,
details
 
of
 
such
 
exchange
 
shall
 
be
 
entered
 
by
 
or
 
on
 
behalf
 
of
 
the
 
Issuer
 
in
 
Schedule
 
Two
and the
 
relevant space
 
in Schedule
 
Two
 
recording any
 
such exchange
 
shall be
 
signed by
or on behalf of
 
the Issuer,
 
whereupon the nominal amount of the
 
Notes represented by this
Global Note shall be increased by the nominal amount any such Temporary
 
Global Note so
exchanged.
In
 
certain
 
circumstances
 
further
 
notes
 
may
 
be
 
issued
 
which
 
are
 
intended
 
on
 
issue
 
to
 
be
consolidated
 
and
 
form
 
a
 
single
 
Series
 
with
 
the
 
Notes.
 
In
 
such
 
circumstances
 
the
 
Issuer
 
shall
procure that:
(i)
 
if
 
the
 
Final
 
Terms
 
indicates
 
that
 
this
 
Global
 
Note
 
is
 
intended
 
to
 
be
 
a
 
New
 
Global
 
Note,
details
 
of
 
such
 
further
 
notes
 
shall
 
be
 
entered
 
in
 
the
 
records
 
of
 
the
 
relevant
 
Clearing
Systems such
 
that the
 
nominal amount
 
of Notes
 
represented by
 
this Global
 
Note shall
 
be
increased by the amount of such further notes so issued; or
0010155-0003327 UKO2:
 
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(ii)
 
if the
 
Final Terms
 
indicates that this
 
Global Note
 
is not
 
intended to
 
be a
 
New Global
 
Note,
details of such further
 
notes shall be entered by
 
or on behalf of the
 
Issuer in Schedule Two
and the
 
relevant space
 
in
 
Schedule
 
Two
 
recording
 
such
 
further
 
notes
 
shall
 
be
 
signed
 
by
or
 
on behalf
 
of
 
the
 
Issuer,
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whereupon the nominal amount of the Notes represented by this
 
Global Note shall be
increased by
 
the nominal amount of any such further notes so issued.
This
 
Global
 
Note may
 
be exchanged
 
in whole
 
but
 
not
 
in
 
part (free
 
of
 
charge) for
 
security printed
Definitive Notes and (if applicable) Coupons and/or Talons
 
in the form set out in
 
Part 3, Part 4
 
and
Part
 
5 respectively
 
of Schedule
 
2 to
 
the Agency
 
Agreement (on
 
the
 
basis that
 
all the
 
appropriate
details
 
have
 
been
 
included on
 
the
 
face
 
of
 
such Definitive
 
Notes
 
and (if
 
applicable)
 
Coupons and
Talons
 
and the Final Terms
 
(or the
 
relevant provisions of the Final Terms)
 
have been endorsed on
or attached to such Definitive Notes) either,
 
as specified in the Final Terms:
(a)
 
upon not less than 60 days' written notice being given to the Agent by Euroclear and/or
Clearstream,
Luxembourg acting on the
 
instructions of any holder
 
of an interest in
 
this Global Note; or
(b)
 
only upon the occurrence
 
of an Exchange Event.
An
Exchange Event
means:
(i)
 
an Event of Default (as defined
 
in Condition 8) has occurred
 
and is continuing; or
(ii)
 
the Issuer
 
has been
 
notified that
 
both the
 
relevant Clearing
 
Systems have
 
been closed
 
for
business for
 
a continuous
 
period of
 
14 days
 
(other than
 
by reason
 
of holiday,
 
statutory or
otherwise) or
 
have announced
 
an intention
 
permanently to
 
cease business
 
or have
 
in fact
done so and no successor clearing system is available.
If this Global Note is
 
only exchangeable following
 
the occurrence of an Exchange
 
Event:
(A)
 
the
 
Issuer
 
will
 
promptly
 
give
 
notice
 
to
 
Noteholders
 
in
 
accordance
 
with
 
Condition
 
12
 
upon
the occurrence of an Exchange Event; and
(B)
 
in the event of the occurrence of any Exchange Event, one or more of the relevant Clearing
Systems acting on the instructions
 
of any holder of an
 
interest in this Global Note
 
may give
notice to
 
the Agent
 
requesting exchange.
 
Any such
 
exchange shall
 
occur no
 
later than
 
45
days after the date of receipt of the first relevant notice by the Agent.
Any such
 
exchange will
 
be made
 
on any
 
day (other
 
than
 
a Saturday
 
or Sunday)
 
on which
 
banks
are open for general business in London by the bearer of
 
this Global Note.
 
On an exchange of this
Global Note, this
 
Global Note shall
 
be surrendered to
 
or to the
 
order of the
 
Agent.
 
The aggregate
nominal amount
 
of Definitive
 
Notes issued
 
upon an
 
exchange of
 
this Global
 
Note will
 
be equal
 
to
the aggregate nominal amount of this Global Note
 
at the time of such exchange.
Until the
 
exchange of
 
this Global
 
Note, the
 
bearer of
 
this Global
 
Note shall
 
in all
 
respects (except
as otherwise provided in this Global Note) be entitled
 
to the same benefits as if he were the
 
bearer
of
 
Definitive
 
Notes
 
and
 
the
 
relative
 
Coupons
 
and/or
 
Talons
 
(if
 
any)
 
represented
 
by
 
this
 
Global
Note.
 
Accordingly,
 
except as
 
ordered by
 
a court of
 
competent jurisdiction or
 
as required by
 
law or
applicable
 
regulation,
 
the
 
Issuer
 
and
 
any
 
Paying
 
Agent
 
may
 
deem
 
and
 
treat
 
the
 
holder
 
of
 
this
Global Note as the absolute owner of this Global Note for all purposes.
In
 
the
 
event
 
that
 
(a)
 
this
 
Global
 
Note
 
(or
 
any
 
part
 
of
 
it)
 
has
 
become
 
due
 
and
 
repayable
 
in
accordance with the Conditions or that the Maturity Date has occurred
 
and, in either case, payment
in full of the amount due has not been made to the bearer in accordance with the provisions set out
above, or
 
(b) following
 
an Exchange
 
Event,
 
this
 
Global
 
Note
 
is
 
not
 
duly
 
exchanged
 
for
 
definitive
Notes
 
by the
 
day provided
 
above,
 
then
 
from
8.00
 
p.m.
 
(London
 
time)
 
on
 
such
 
day
 
each
 
Noteholder
 
will
 
become
 
entitled
 
to
 
proceed
 
directly
against the Issuer on, and subject to, the terms of the Deed of Covenant executed by the Issuer on
13
 
May
 
2020
 
(as
 
amended,
 
supplemented,
 
novated
 
and/or
 
restated
 
as
 
at
 
the
 
Issue
 
Date)
 
in
0010155-0003327 UKO2:
 
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respect of the Notes
 
and the bearer
 
 
 
 
0010155-0003327 UKO2:
 
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will
 
have
 
no
 
further
 
rights
 
under
 
this
 
Global
 
Note
 
(but
 
without
 
prejudice
 
to
 
the
 
rights
 
which
 
the
bearer or any other person may have under the Deed of Covenant).
No
 
rights
 
are
 
conferred on
 
any
 
person
 
under the
 
Contracts (Rights
 
of
 
Third
 
Parties)
 
Act
 
1999
 
to
enforce
 
any
 
term
 
of
 
this
 
Global
 
Note,
 
but
 
this
 
does
 
not
 
affect
 
any
 
right
 
or
 
remedy
 
of
 
any
 
person
which exists or is available apart from that Act.
If
 
any
 
provision
 
in
 
or
 
obligation
 
under
 
this
 
Global
 
Note
 
is
 
or
 
becomes
 
invalid,
 
illegal
 
or
unenforceable in
 
any respect
 
under the
 
law of
 
any jurisdiction,
 
that will
 
not
 
affect or
 
impair (i)
 
the
validity,
 
legality
 
or
 
enforceability
 
under
 
the
 
law
 
of
 
that
 
jurisdiction
 
of
 
any
 
other
 
provision
 
in
 
or
obligation under this Global Note, and
 
(ii) the validity,
 
legality or enforceability under the law of
 
any
other jurisdiction of that or any
 
other provision in or obligation under this Global Note.
This
 
Global
 
Note
 
and
 
any
 
non-contractual
 
obligations
 
arising
 
out
 
of
 
or
 
in
 
connection
 
with
 
it
 
are
governed by, and shall be construed in accordance with, English law.
This
 
Global
 
Note
 
shall
 
not
 
be
 
valid
 
unless
 
authenticated
 
by
 
the
 
Agent
 
and,
 
if
 
the
 
Final
 
Terms
indicates that this Global Note is intended to be a NGN (i) which is intended to be held in a
 
manner
which
 
would
 
allow
 
Eurosystem
 
eligibility
 
or
 
(ii)
 
in
 
respect
 
of
 
which
 
effectuation
 
is
 
applicable,
effectuated by the entity
 
appointed as common safekeeper by the relevant Clearing Systems.
IN WITNESS
whereof the Issuer has caused
 
this Global Note to be duly
 
executed on its behalf.
EQUINOR ASA
By:
Authenticated without
 
recourse,
warranty or liability by
THE
 
BANK
 
OF
 
NEW
 
YORK
MELLON
By:
Effectuated without
recourse, warranty or
liability by
...................................................
as common safekeeper
By:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
0010155-0003327 UKO2:
 
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SCHEDULE ONE TO THE
 
PERMANENT GLOBAL
 
NOTE
3
PART 1
INTEREST PAYMENTS
Date made
Total
 
amount of interest
payable
Amount of interest paid
Confirmation of payment
on
behalf of the Issuer
3
 
Schedule One should
 
only be completed
 
where the Final
 
Terms indicates that this Global Note
 
is not intended to
 
be a New
Global Note.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
*
See the most recent entry
 
in Part 2 or 3 of
 
Schedule One or in
 
Schedule Two in order to determine
this amount.
0010155-0003327 UKO2:
 
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PART 2
REDEMPTIONS
Date
made
Total
 
amount
of principal
payable
Amount of
principal paid
Remaining nominal
amount of
 
this
Global Note
following such
redemption
*
Confirmation of
redemption on
behalf of
 
the
Issuer
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
*
See the most recent entry
 
in Part 2 or 3 of
 
Schedule One or in
 
Schedule Two in order to determine
this amount.
0010155-0003327 UKO2:
 
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PART 3
PURCHASES AND CANCELLATIONS
Date
made
Part of nominal amount
of this Global
 
Note
purchased and
cancelled
Remaining nominal
amount of this
 
Global Note
following such purchase
and cancellation
*
Confirmation
 
of
purchase
 
and
cancellation
 
on
 
behalf
of the Issuer
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
0010155-0003327 UKO2:
 
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SCHEDULE TWO TO THE PERMANENT GLOBAL NOTE
4
SCHEDULE OF EXCHANGES
 
AND ISSUES OF FURTHER
NOTES
The following exchanges
 
or further notes affecting the nominal
 
amount of this Global Note
 
have been
made:
Date
made
Nominal amount of
Temporary Global
Note exchanged for
this Global Note or
nominal amount of
further notes issued
Remaining nominal
amount of this Global
Note following such
exchange or further
notes issued
*
Notation made
 
on
behalf of the Issuer
 
 
0010155-0003327 UKO2:
 
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110
4
 
Schedule Two should only be
 
completed where the Final
 
Terms indicates that this Global Note is
 
not intended to
 
be a New
Global Note.
*
 
See the most recent entry
 
in Part 2 or 3 of
 
Schedule One or in
 
Schedule Two in order to determine
 
this amount.
 
0010155-0003327 UKO2:
 
2004375908.9
111
PART 3
FORM OF DEFINITIVE
 
NOTE
(
Face of Note
)
[ANY
 
UNITED
 
STATES
 
PERSON
 
WHO
 
HOLDS
 
THIS
 
OBLIGATION
 
WILL
 
BE
 
SUBJECT
 
TO
LIMITATIONS
 
UNDER
 
THE
 
UNITED
 
STATES
 
INCOME
 
TAX
 
LAWS
 
INCLUDING
 
THE
LIMITATIONS
 
PROVIDED
 
IN
 
SECTIONS
 
165(j)
 
AND
 
1287(a)
 
OF
 
THE
 
INTERNAL
 
REVENUE
CODE.]
(1)
EQUINOR ASA
unconditionally and (subject
 
to Condition 2(c)) irrevocably
guaranteed by EQUINOR ENERGY AS
[
Specified Currency and Nominal Amount of Tranche
]
EURO MEDIUM TERM
 
NOTES DUE [
Year of Maturity
]
This
 
Note
 
is
 
one
 
of
 
a
 
duly
 
authorised
 
issue
 
of
 
Euro
 
Medium
 
Term
 
Notes
 
denominated
 
in
 
the
Specified
 
Currency
 
maturing
 
on
 
the
 
Maturity
 
Date
 
(the
Notes
)
 
of
 
Equinor
 
ASA
 
(the
Issuer
).
References herein to
 
the Conditions shall
 
be to the
 
Terms
 
and Conditions of
 
the Notes
 
other than
VPS Notes
 
[endorsed hereon/set
 
out in
 
Schedule 1
 
to the
 
Agency Agreement
 
(as defined
 
below)
which shall be
 
incorporated by reference
 
herein and have
 
effect as
 
if set out
 
herein] as completed
by
 
the
 
Final
 
Terms
 
(the
Final
 
Terms
)
 
(or
 
the
 
relevant
 
provisions
 
of
 
the
 
Final
 
Terms)
 
endorsed
hereon,
 
but
 
in
 
the
 
event
 
of
 
any
 
conflict
 
between
 
the
 
provisions
 
of
 
the
 
Conditions
 
and
 
the
information in the Final Terms, the Final Terms
 
will prevail.
This
 
Note
 
is
 
issued
 
subject
 
to,
 
and
 
with
 
the
 
benefit
 
of,
 
the
 
Conditions
 
and
 
an
 
amended
 
and
restated
 
Agency Agreement
 
(the
Agency
 
Agreement
,
 
which expression
 
shall be
 
construed as
 
a
reference to that agreement as the same may be
 
amended, supplemented or restated from time to
time)
 
dated
 
9
 
May
 
2022
 
and
 
made
 
between
 
[(
inter
 
alios
)]
 
the
 
Issuer,
 
Equinor
 
Energy
 
AS
 
as
guarantor, The Bank of New York
 
Mellon, London Branch (the
Agent
) and the other parties named
therein.
For value
 
received, the
 
Issuer,
 
subject to
 
and in
 
accordance with
 
the Conditions,
 
promises to
 
pay
to the
 
bearer hereof on the
 
Maturity Date and/or on
 
such earlier date(s)
 
as this Note
 
may become
due and repayable in accordance with
 
the Conditions, the amount payable under
 
the Conditions in
respect
 
of
 
this
 
Note
 
on
 
each
 
such
 
date
 
and
 
to
 
pay
 
interest
 
(if
 
any)
 
on
 
this
 
Note
 
calculated
 
and
payable as provided in the Conditions together with any other
 
sums payable under the Conditions.
If
 
any
 
provision in
 
or
 
obligation under
 
this
 
Note
 
is
 
or
 
becomes
 
invalid, illegal
 
or
 
unenforceable in
any
 
respect under the law
 
of any jurisdiction, that
 
will not affect or
 
impair (i) the validity,
 
legality or
enforceability
 
under
 
the
 
law
 
of
 
that
 
jurisdiction
 
of
 
any
 
other
 
provision
 
in
 
or
 
obligation
 
under
 
this
Note, and
(ii) the
 
validity,
 
legality or
 
enforceability under
 
the law
 
of any
 
other jurisdiction
 
of that
 
or any
 
other
provision in or obligation under this Note.
This Note shall not be
 
validly issued unless authenticated
 
by the Agent.
IN WITNESS
whereof the Issuer has caused
 
this Note to be duly
 
executed on its behalf.
EQUINOR ASA
0010155-0003327 UKO2:
 
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112
(1)
 
This legend can be
 
deleted if TEFRA C
 
or TEFRA not applicable
 
is specified in the
 
applicable Final Terms.
0010155-0003327 UKO2:
 
2004375908.9
113
By:
 
............................................
Authorised Signatory
Authenticated without
 
recourse,
warranty or liability by
THE BANK OF NEW
 
YORK MELLON, LONDON
 
BRANCH
By:
0010155-0003327 UKO2:
 
2004375908.9
114
(
Reverse of Note
)
Terms and Conditions of the Notes other
 
than VPS Notes
[
Terms and Conditions of the Notes other than VPS
 
Notes to be as
set out in Schedule 1 to the Agency Agreement
]
Final Terms
[
Here may be set
 
out text of Final
Terms relating to the Notes
]
exhibit25p116i0
 
0010155-0003327 UKO2:
 
2004375908.9
115
PART 4
FORM OF
 
COUPON
(
Face of Coupon
)
EQUINOR ASA
[
Specified Currency and
 
Nominal Amount Tranche
]
NOTES DUE [
Year of Maturity
]
Series No. [
 
]
Part A
[
For Fixed Rate Notes
:
This Coupon is payable to bearer, separately
 
Coupon
for negotiable and subject to the Terms and
 
[
]
Conditions of the Notes other than
VPS Notes of the said Notes.
 
due
on [
 
]
20[
 
]]
Part B
[
For Floating Rate Notes
:
Coupon for the amount due in accordance with
 
Coupon
due the Terms
 
and Conditions of the Notes other than
VPS Notes on the said
 
Notes on
 
in [
 
]
the Interest Payment Date falling
 
in
 
20[
 
]]
[
 
] 20[
 
].
This Coupon is payable
 
to bearer,
separately negotiable and subject to
such Terms
 
and Conditions of the Notes
other than
VPS Notes, under which
 
it may become
void before its due date.]
ANY
 
UNITED
 
STATES
 
PERSON
 
WHO
 
HOLDS
 
THIS
 
OBLIGATION
 
WILL
 
BE
 
SUBJECT
 
TO
LIMITATIONS
 
UNDER
 
THE
 
UNITED
 
STATES
 
TAX
 
LAWS
 
INCLUDING
 
THE
 
LIMITATIONS
PROVIDED IN SECTIONS 165(j) AND 1287(a) OF THE INTERNAL
 
REVENUE CODE.
00
 
000000
 
[ISIN]
 
00
 
000000
0010155-0003327 UKO2:
 
2004375908.9
116
PART 5
FORM OF
 
TALON
(
Face of Talon
)
ANY
 
UNITED
 
STATES
 
PERSON
 
WHO
 
HOLDS
 
THIS
 
OBLIGATION
 
WILL
 
BE
 
SUBJECT
 
TO
LIMITATIONS
 
UNDER
 
THE
 
UNITED
 
STATES
 
INCOME
 
TAX
 
LAWS
 
INCLUDING
 
THE
LIMITATIONS
 
PROVIDED
 
IN
 
SECTIONS
 
165(j)
 
AND
 
1287(a)
 
OF
 
THE
 
INTERNAL
 
REVENUE
CODE.
EQUINOR ASA
[
Specified Currency and Nominal Amount of
Tranche
] EURO MEDIUM TERM
 
NOTES DUE [
Year
of Maturity
]
Series No. [
 
]
On and after
 
[
 
] further Coupons
 
[and a further
 
Talon]
 
appertaining to the
 
Note to which
 
this Talon
appertains will be issued at the specified office of the
 
Agent or any of the Paying Agents set out on
the reverse hereof (and/or any
 
other or further Paying Agents
 
and/or specified offices as may
 
from
time to
 
time be
 
duly appointed
 
and notified
 
to the
 
Noteholders) upon
 
production and
 
surrender of
this Talon.
This
 
Talon
 
may,
 
in
 
certain
 
circumstances,
 
become
 
void
 
under
 
the
 
Terms
 
and
 
Conditions
 
of
 
the
Notes other than VPS Notes endorsed on the Notes to which
 
this Talon
 
appertains.
EQUINOR ASA
By:
 
............................................
Authorised Signatory
0010155-0003327 UKO2:
 
2004375908.9
117
(
Reverse of Coupon and
 
Talon
)
AGENT
The Bank of New
 
York Mellon, London
Branch One Canada Square
London E14
 
5AL
United Kingdom
PAYING
 
AGENT
The Bank of New York Mellon SA/NV, Luxembourg Branch
Vertigo Building - Polaris
2-4 rue,
 
Eugène
Ruppert L-2453
Luxembourg
and/or such other or further Agent and other or further Paying
 
Agents and/or specified offices as
may from time to time be duly appointed by the Issuer and notice of
 
which has been given to the
Noteholders.
0010155-0003327 UKO2:
 
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118
SCHEDULE 3
FORM OF DEED OF COVENANT
THIS DEED OF
 
COVENANT
is made on 13 May 2020 by
EQUINOR ASA
(the
Issuer
) in favour of
the
 
account holders
 
specified below
 
of Clearstream
 
Banking S.A.,
 
Euroclear Bank
 
SA/NV,
 
and/or
any
 
other
 
additional
 
clearing
 
system
 
or
 
systems
 
as
 
are
 
specified
 
in
 
Part
 
B
 
of
 
the
 
Final
 
Terms
relating to any Note (as defined below) (each a
Clearing System
).
WHEREAS
:
(A)
 
The
 
Issuer
 
has
 
entered
 
into
 
an
 
amended
 
and
 
restated
 
Programme
 
Agreement
 
(the
Programme
 
Agreement
,
 
which
 
expression
 
includes
 
the
 
same
 
as
 
it
 
may
 
be
 
further
amended and/or
 
restated and/or supplemented
 
from time
 
to time)
 
dated 13 May
 
2020 with
the
 
Dealers
 
named
 
therein
 
under
 
which
 
the
 
Issuer
 
proposes
 
from
 
time
 
to
 
time
 
to
 
issue
Euro Medium Term
 
Notes (the
Notes
).
(B)
 
The
 
Notes
 
(other
 
than
 
the
 
VPS
 
Notes
 
(as
 
defined
 
in
 
the
 
Programme
 
Agreement))
 
will
initially
 
be
 
represented
 
by,
 
and
 
comprised
 
in,
 
Temporary
 
Global
 
Notes
 
(the
Temporary
Global Notes
) and thereafter may be represented by,
 
and comprised in, Permanent Global
Notes (the
Permanent Global
 
Notes
, the
 
Temporary
 
Global Notes
 
and Permanent Global
Notes
 
being
 
herein
 
together
 
called
 
the
Global
 
Notes
)
 
representing
 
a
 
certain
 
number
 
of
underlying Notes (the
Underlying Notes
).
(C)
 
Each Global Note may, after
 
issue, be deposited with a depositary for one or more Clearing
Systems (each such
 
Clearing System or
 
all such Clearing
 
Systems together,
 
the
Relevant
Clearing
 
System
). Upon
 
such deposit
 
of a
 
Global Note
 
the Underlying
 
Notes represented
by such
 
Global Note will
 
be credited to
 
a securities account
 
or securities accounts
 
with the
Relevant
 
Clearing
 
System.
 
Any
 
account
 
holder
 
with
 
the
 
Relevant
 
Clearing
 
System
 
which
has Underlying Notes
 
credited to its
 
securities account from
 
time to time
 
(each a
Relevant
Account
 
Holder
)
 
will,
 
subject
 
to
 
and
 
in
 
accordance
 
with
 
the
 
terms
 
and
 
conditions
 
and
operating
 
procedures
 
or
 
management
 
regulations
 
of
 
the
 
Relevant
 
Clearing
 
System,
 
be
entitled to transfer such Underlying Notes and
 
(subject to and upon payment being made by
the
 
Issuer to
 
the
 
bearer in
 
accordance
 
with the
 
terms
 
of
 
the
 
relevant Global
 
Note)
 
will be
entitled to receive
 
payments from the Relevant
 
Clearing System calculated by
 
reference to
the Underlying Notes credited to its securities account.
(D)
 
In
 
certain circumstances
 
specified in
 
each Global
 
Note,
 
the
 
bearer of
 
the
 
Global
 
Note will
have no
 
further rights
 
under the
 
Global Note
 
(but without
 
prejudice to
 
the rights
 
which any
person
 
may
 
have
 
pursuant
 
to
 
this
 
Deed
 
of
 
Covenant).
 
The
 
time
 
at
 
which
 
this
 
occurs
 
is
hereinafter
 
referred
 
to
 
as
 
the
Relevant
 
Time
.
 
In
 
such
 
circumstances
 
each
 
Relevant
Account
 
Holder
 
will,
 
subject
 
to
 
and
 
in
 
accordance
 
with
 
the
 
terms
 
of
 
this
 
Deed,
 
acquire
against the
 
Issuer all
 
those rights
 
which such
 
Relevant Account
 
Holder would
 
have had
 
if,
prior to
 
the Relevant
 
Time,
 
duly executed
 
and authenticated
 
Definitive Note(s)
 
(as defined
in the Agency Agreement (the
Agency Agreement
, which expression includes the same as
it
 
may
 
be further
 
amended and/or
 
restated
 
and/or
 
supplemented from
 
time
 
to
 
time)
 
dated
13 May 2020) and interest coupons (the
Coupons
) appertaining to the Definitive Note(s) (if
appropriate)
 
had
 
been
 
issued
 
in
 
respect
 
of
 
its
 
Underlying
 
Note(s)
 
and
 
such
 
Definitive
Notes(s) and
 
Coupons (if
 
appropriate) were
 
held and
 
beneficially owned
 
by such
 
Relevant
Account Holder.
NOW THIS DEED WITNESSES
 
AS FOLLOWS
:
1.
 
If
 
at
 
any
 
time
 
the
 
bearer
 
of
 
the
 
Global
 
Note
 
ceases to
 
have
 
rights
 
under
 
it
 
in
 
accordance
with
 
the
 
terms
 
thereof,
 
the
 
Issuer
 
hereby
 
undertakes
 
and
 
covenants
 
with
 
each
 
Relevant
0010155-0003327 UKO2:
 
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119
Account
 
Holder
 
(other
 
than
 
when
 
any
 
Relevant
 
Clearing
 
System
 
is
 
an
 
account
 
holder
 
of
any
 
other
 
Relevant
 
Clearing
 
System)
 
that
 
each
 
Relevant
 
Account
 
Holder
 
shall
automatically
 
acquire
 
at
 
the
 
Relevant
 
Time,
0010155-0003327 UKO2:
 
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120
without the
 
need for any
 
further action on
 
behalf of any
 
person, against the
 
relevant Issuer
all
 
those
 
rights
 
which
 
such
 
Relevant
 
Account
 
Holder
 
would
 
have
 
had
 
if
 
at
 
the
 
Relevant
Time it
 
held and beneficially owned duly
 
executed and authenticated Definitive Note(s)
 
and
Coupons
 
(if
 
appropriate)
 
in
 
respect
 
of
 
each
 
Underlying
 
Note
 
represented
 
by
 
such
 
Global
Note
 
which
 
such
 
Relevant
 
Account
 
Holder
 
has
 
credited
 
to
 
its
 
securities
 
account
 
with
 
the
Relevant
 
Clearing
 
System
 
at
 
the
 
Relevant
 
Time.
 
The
 
Issuer's
 
obligation
 
pursuant
 
to
 
this
clause
 
shall
 
be
 
a
 
separate
 
and
 
independent
 
obligation
 
by
 
reference
 
to
 
each
 
Underlying
Note
 
which
 
a
 
Relevant
 
Account
 
Holder
 
has
 
credited
 
to
 
its
 
securities
 
account
 
with
 
the
Relevant
 
Clearing
 
System
 
and
 
the
 
Issuer
 
agrees
 
that
 
a
 
Relevant
 
Account
 
Holder
 
may
assign its rights hereunder in whole or in part.
2.
 
The records of the Relevant Clearing System shall be
 
conclusive evidence of the identity of
the
 
Relevant
 
Account
 
Holders
 
and
 
the
 
number
 
of
 
Underlying
 
Notes
 
credited
 
to
 
the
securities account
 
of each
 
Relevant Account
 
Holder.
 
For the
 
purposes hereof
 
a statement
issued by the Relevant Clearing System stating:
(a)
 
the name of the Relevant
 
Account Holder to which
 
such statement is issued;
 
and
(b)
 
the
 
aggregate
 
nominal
 
amount
 
of
 
Underlying
 
Notes
 
credited
 
to
 
the
 
securities
account of such
 
Relevant Account Holder
 
as at the
 
opening of business
 
on the first
day following the Relevant
 
Time on which the
 
Relevant Clearing System is open for
business,
shall be conclusive evidence
 
of the records of
 
the Relevant Clearing System at
 
the Relevant
Time.
3.
 
In the
 
event of
 
a dispute, the
 
determination of the
 
Relevant Time
 
by the Relevant
 
Clearing
System
 
(in the
 
absence of
 
manifest error)
 
shall be
 
final and
 
conclusive for
 
all purposes
 
in
connection
 
with
 
the
 
Relevant
 
Account
 
Holders
 
with
 
securities
 
accounts with
 
the
 
Relevant
Clearing System.
4.
 
The
 
Issuer
 
undertakes
 
in
 
favour
 
of
 
each
 
Relevant
 
Account
 
Holder
 
that,
 
in
 
relation
 
to
 
any
payment to be
 
made by it
 
under this Deed,
 
it will comply
 
with the
 
provisions of Condition
 
6
to
 
the
 
extent
 
that
 
they
 
apply
 
to
 
any
 
payments
 
in
 
respect
 
of
 
Underlying
 
Notes
 
as
 
if
 
those
provisions had been set out in full in this Deed.
5.
 
The Issuer
 
agrees to
 
pay any
 
stamp and
 
other similar
 
duties and
 
taxes, including
 
interest
and penalties,
 
payable on
 
or in
 
connection with
 
the execution
 
of this
 
Deed and
 
any action
taken by any Relevant Account Holder to enforce the provisions of
 
this Deed.
6.
 
The Issuer hereby
 
warrants, represents and covenants
 
with each Relevant
 
Account Holder
that
 
it
 
has
 
all
 
corporate
 
power,
 
and
 
has
 
taken
 
all
 
necessary
 
corporate
 
or
 
other
 
steps,
 
to
enable it
 
to execute,
 
deliver and
 
perform this
 
Deed, and
 
that this
 
Deed constitutes
 
a legal,
valid and
 
binding obligation
 
of the
 
Issuer enforceable
 
in accordance
 
with its
 
terms subject
to the laws of bankruptcy and other laws affecting the rights of creditors
 
generally.
7.
 
This Deed
 
shall take
 
effect as
 
a Deed
 
Poll for
 
the benefit
 
of the
 
Relevant Account
 
Holders
from time to time and for
 
the time being.
 
This Deed shall be deposited with and
 
held by the
depositary or
 
common safekeeper,
 
as the
 
case may
 
be, for
 
the Relevant
 
Clearing System
(being
 
at
 
the
 
date
 
hereof
 
The
 
Bank
 
of
 
New
 
York
 
Mellon
 
at
 
One
 
Canada Square,
 
London
E14 5AL) until all the obligations of the Issuer hereunder have been discharged
 
in full.
8.
 
The
 
Issuer
 
hereby
 
acknowledges
 
the
 
right
 
of
 
every
 
Relevant
 
Account
 
Holder
 
to
 
the
production of, and the
 
right of every Relevant Account
 
Holder to obtain (upon payment
 
of a
reasonable charge) a copy of,
 
this Deed, and further
 
acknowledges and covenants that the
obligations
 
binding
 
upon
 
it
 
contained herein
 
are
 
owed
 
to,
 
and
 
shall
 
be for
 
the
 
account of,
0010155-0003327 UKO2:
 
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121
each and
 
every Relevant Account
 
Holder,
 
and that
 
each Relevant Account
 
Holder shall be
entitled severally to enforce the said obligations against the
 
Issuer.
0010155-0003327 UKO2:
 
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122
9.
 
If
 
any
 
provision
 
in
 
or
 
obligation
 
under
 
this
 
Deed
 
is
 
or
 
becomes
 
invalid,
 
illegal
 
or
unenforceable in
 
any respect
 
under the
 
law of
 
any jurisdiction,
 
that will
 
not affect
 
or impair
(i)
 
the
 
validity,
 
legality
 
or
 
enforceability
 
under
 
the
 
law
 
of
 
that
 
jurisdiction
 
of
 
any
 
other
provision
 
in
 
or
 
obligation
 
under
 
this
 
Deed,
 
and
 
(ii)
 
the
 
validity,
 
legality
 
or
 
enforceability
under the
 
law of
 
any other
 
jurisdiction of
 
that or
 
any other
 
provision in
 
or obligation
 
under
this Deed.
10.
 
This
 
Deed
 
and
 
any
 
non-contractual
 
obligations
 
arising
 
out
 
of
 
or
 
in
 
connection
 
with
 
it
 
are
governed by, and shall be construed in accordance with, English law.
The courts of
 
England are to have
 
jurisdiction to settle any
 
disputes which may arise
 
out of
or
 
in
 
connection
 
with
 
this
 
Agreement
 
(including
 
a
 
dispute
 
relating
 
to
 
any
 
non-contractual
obligations
 
arising
 
out
 
of
 
or
 
in
 
connection
 
with
 
this
 
Agreement)
 
and
 
accordingly any
 
legal
action
 
or
 
proceedings
 
arising
 
out
 
of
 
or
 
in
 
connection
 
with
 
this
 
Agreement
 
(
Proceedings
)
may
 
be
 
brought
 
in
 
such
 
courts.
 
The
 
Issuer
 
irrevocably
 
submits
 
to
 
the
 
jurisdiction
 
of
 
such
courts and
 
waives any
 
objection to Proceedings
 
in any
 
such courts whether
 
on the
 
ground
of
 
venue
 
or
 
on
 
the
 
ground
 
that
 
the
 
Proceedings
 
have
 
been
 
brought
 
in
 
an
 
inconvenient
forum.
 
This
 
submission
 
is
 
made
 
for
 
the
 
benefit
 
of
 
each
 
of
 
the
 
Relevant
 
Account
 
Holders
and, to
 
the extent
 
allowed by
 
applicable law,
 
shall not
 
limit
 
the right
 
or any
 
of them to
 
take
Proceedings in any other court of competent
 
jurisdiction nor shall the taking of Proceedings
in
 
one
 
or
 
more
 
jurisdictions
 
preclude
 
the
 
taking
 
of
 
Proceedings
 
in
 
any
 
other
 
jurisdiction
(whether concurrently or not).
The
 
Issuer
 
irrevocably appoints
 
Equinor
 
UK
 
Limited (whose
 
offices
 
are
 
at
 
the
 
date
 
of
 
this
Agreement at One Kingdom Street, Paddington Central,
 
London W2 6BD) as its authorised
agent
 
for
 
service
 
of
 
process
 
in
 
England.
 
If
 
for
 
any
 
reason
 
such
 
agent
 
shall
 
cease
 
to
 
be
such
 
agent
 
for
 
service
 
of
 
process,
 
the
 
Issuer
 
shall
 
forthwith,
 
on
 
request
 
of
 
the
 
Agent,
appoint a
 
new agent
 
for service
 
of
 
process in
 
England and
 
deliver to
 
the Agent
 
a copy
 
of
the new agent's
 
acceptance of that
 
appointment within 30 days.
 
Nothing in this Agreement
shall affect the right to serve process in any other manner permitted by law.
IN
 
WITNESS
whereof
 
the
 
Issuer
 
has
 
caused
 
this
 
Deed
 
to
 
be
 
duly
 
executed
 
the
 
day and
 
year
first
 
above mentioned.
EXECUTED
as a
DEED
)
by EQUINOR ASA and signed
 
and
 
)
delivered as a deed on its
 
)
behalf by
 
)
an authorised representative of
 
the company
 
)
0010155-0003327 UKO2:
 
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123
SCHEDULE 4
PROVISIONS FOR MEETINGS
 
OF NOTEHOLDERS
1.
 
As
 
used
 
in
 
this
 
Schedule
 
the
 
following
 
expressions
 
shall
 
have
 
the
 
following
 
meanings
unless
 
the context otherwise requires:
(a)
voting certificate
shall mean an English language certificate issued by a Paying
Agent and dated in which it is stated:
(i)
 
that on
 
the date
 
thereof Notes
 
(not being
 
Notes in
 
respect of
 
which a
 
block
voting
 
instruction
 
has
 
been
 
issued
 
and
 
is
 
outstanding
 
in
 
respect
 
of
 
the
meeting specified in such voting certificate and any adjourned such meeting)
bearing specified
 
serial numbers
 
were deposited
 
with such
 
Paying Agent
 
or
(to the
 
satisfaction of
 
such Paying
 
Agent) were
 
held to
 
its order
 
or under
 
its
control and that no such Notes will cease to be so
 
deposited or held until the
first to occur of:
(A)
 
the
 
conclusion
 
of
 
the
 
meeting
 
specified
 
in
 
such
 
certificate
 
or,
 
if
applicable, any adjourned such meeting; and
(B)
 
the
 
surrender
 
of
 
the
 
certificate
 
to
 
the
 
Paying
 
Agent
 
who
 
issued
 
the
same;
 
and
(ii)
 
that the bearer thereof is entitled to attend and vote at such meeting and any
adjourned
 
such
 
meeting
 
in
 
respect
 
of
 
the
 
Notes
 
represented
 
by
 
such
certificate;
(b)
block
 
voting
 
instruction
shall
 
mean
 
an
 
English
 
language
 
document
 
issued
 
by
a
 
Paying Agent and dated in which:
(i)
 
it
 
is
 
certified
 
that
 
Notes
 
(not
 
being
 
Notes
 
in
 
respect
 
of
 
which
 
a
 
voting
certificate
 
has
 
been
 
issued
 
and
 
is
 
outstanding
 
in
 
respect
 
of
 
the
 
meeting
specified
 
in
 
such
 
block
 
voting
 
instruction and
 
any
 
adjourned such
 
meeting)
have been
 
deposited with
 
such Paying
 
Agent or
 
(to the
 
satisfaction of
 
such
Paying
 
Agent)
 
were
 
held
 
to
 
its
 
order
 
or
 
under
 
its
 
control
 
and
 
that
 
no
 
such
Notes will cease to be so deposited or held until the first to
 
occur of:
(A)
 
the
 
conclusion
 
of
 
the
 
meeting
 
specified
 
in
 
such
 
document
 
or,
 
if
applicable, any adjourned such meeting; and
(B)
 
the surrender
 
to the
 
Paying Agent
 
not less
 
than 48
 
hours before
 
the
time
 
for
 
which
 
such
 
meeting
 
or
 
any
 
adjourned
 
such
 
meeting
 
is
convened
 
of
 
the
 
receipt
 
issued
 
by
 
such
 
Paying
 
Agent
 
in
 
respect
 
of
each
 
such
 
deposited
 
Note
 
which
 
is
 
to
 
be
 
released
 
or
 
(as
 
the
 
case
may
 
require)
 
the
 
Note
 
or
 
Notes
 
ceasing
 
with
 
the
 
agreement
 
of
 
the
Paying Agent to be held to its order or under its control and the giving
of
 
notice
 
by
 
the
 
Paying
 
Agent
 
to
 
the
 
Issuer
 
in
 
accordance
 
with
paragraph
 
hereof of the necessary amendment to the block voting
instruction;
(ii)
 
it
 
is
 
certified
 
that
 
each
 
holder
 
of
 
such
 
Notes
 
has
 
instructed
 
such
 
Paying
Agent that the
 
vote(s) attributable to
 
the Note
 
or Notes
 
so deposited or
 
held
should be
 
cast in
 
a particular
 
way in
 
relation to
 
the resolution
 
or resolutions
to be
 
put to
 
such meeting
 
or any
 
adjourned such
 
meeting and
 
that all
 
such
0010155-0003327 UKO2:
 
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instructions
 
are
 
during
 
the
 
period
 
commencing
 
48
 
hours
 
prior
 
to
 
the
 
time
for
 
which
 
such
 
meeting
 
or
 
any
 
adjourned
0010155-0003327 UKO2:
 
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125
such
 
meeting
 
is
 
convened
 
and
 
ending
 
at
 
the
 
conclusion
 
or
 
adjournment
thereof neither revocable nor capable of amendment;
(iii)
 
the
 
total
 
number
 
and the
 
serial
 
numbers
 
of
 
the
 
Notes
 
so
 
deposited or
 
held
are
 
listed
 
distinguishing with
 
regard
 
to
 
each such
 
resolution between
 
those
in respect
 
of which
 
instructions have
 
been given as
 
aforesaid that the
 
votes
attributable
 
thereto
 
should
 
be
 
cast
 
in
 
favour
 
of
 
the
 
resolution
 
and
 
those
 
in
respect of
 
which instructions
 
have been
 
so given
 
that the
 
votes attributable
thereto should be cast against the resolution; and
(iv)
 
one
 
or
 
more
 
persons
 
named
 
in
 
such
 
document
 
(each
 
hereinafter
 
called
 
a
proxy
) is
 
or are authorised
 
and instructed by
 
such Paying Agent
 
to cast
 
the
votes
 
attributable to
 
the
 
Notes
 
so
 
listed
 
in
 
accordance with
 
the
 
instructions
referred to in paragraph (iii) above as set out in such document.
The
 
holder
 
of
 
any
 
voting
 
certificate
 
or
 
the
 
proxies
 
named
 
in
 
any
 
block
 
voting
instruction
 
shall
 
for
 
all
 
purposes
 
in
 
connection
 
with
 
the
 
relevant
 
meeting
 
or
adjourned meeting of Noteholders be deemed to be the holder of the Notes to which
such voting
 
certificate or
 
block voting
 
instruction relates
 
and the
 
Paying Agent
 
with
which such Notes have been
 
deposited or the person holding the
 
same to the order
or under the control of such Paying Agent shall be deemed for such purposes not to
be the holder of those Notes.
(c)
 
References herein to the
Notes
are to the Notes in respect of which the relevant
meeting is convened.
2.
 
The
 
Issuer
 
may
 
at
 
any
 
time
 
and,
 
upon
 
a
 
requisition
 
in
 
writing
 
of
 
Noteholders
 
holding
 
not
less than
 
10 per cent. in
 
nominal amount of the Notes for
 
the time being outstanding, shall
convene a meeting of the Noteholders and if
 
the Issuer makes default for a period of
 
seven
days
 
in
 
convening
 
such
 
a
 
meeting
 
the
 
same
 
may
 
be
 
convened
 
by
 
the
 
requisitionists.
Whenever the
 
Issuer is
 
about to
 
convene any
 
such meeting
 
it shall
 
forthwith give
 
notice in
writing to the
 
Agent and the
 
Dealers of the
 
day,
 
time and place
 
thereof (which need
 
not be
a
 
physical
 
place
 
and
 
instead
 
may
 
be
 
by
 
way
 
of
 
conference
 
call,
 
including
 
by
 
use
 
of
 
a
videoconference
 
platform)
 
and
 
of
 
the
 
nature
 
of
 
the
 
business
 
to
 
be
 
transacted
 
thereat.
Every such meeting shall be held at such time and place as
 
the Agent may approve.
3.
 
At
 
least 21
 
days' notice
 
(exclusive of
 
the day
 
on which
 
the notice
 
is given
 
and the
 
day on
which the
 
meeting is
 
held) specifying
 
the place,
 
day and
 
hour of
 
meeting shall
 
be given
 
to
the
 
Noteholders
 
prior
 
to
 
any
 
meeting
 
of
 
the
 
Noteholders
 
in
 
the
 
manner
 
provided
 
by
Condition 12.
 
Such notice shall
 
state generally the
 
nature of the
 
business to be
 
transacted
at
 
the
 
meeting
 
thereby
 
convened
 
but
 
(except
 
for
 
an
 
Extraordinary
 
Resolution)
 
it
 
shall
 
not
be
 
necessary
 
to
 
specify
 
in
 
such
 
notice
 
the
 
terms
 
of
 
any
 
resolution
 
to
 
be
 
proposed.
 
Such
notice
 
shall
 
include
 
a
 
statement
 
to
 
the
 
effect
 
that
 
Notes
 
may
 
be
 
deposited
 
with
 
Paying
Agents for the purpose of obtaining voting certificates or appointing proxies not less than 24
hours
 
before
 
the
 
time
 
fixed
 
for
 
the
 
meeting
 
or
 
that,
 
in
 
the
 
case
 
of
 
corporations, they
 
may
appoint representatives
 
by resolution
 
of their
 
directors or
 
other governing
 
body.
 
A copy
 
of
the
 
notice
 
shall
 
be
 
sent
 
by
 
post
 
to
 
the
 
Issuer
 
(unless
 
the
 
meeting
 
is
 
convened
 
by
 
the
Issuer).
4.
 
Some person
 
(who may
 
but need
 
not be
 
a Noteholder)
 
nominated in
 
writing by
 
the Issuer
shall be
 
entitled to
 
take the chair
 
at every
 
such meeting but
 
if no
 
such nomination is
 
made
or if
 
at any
 
meeting the
 
person nominated
 
shall not
 
be present
 
within fifteen
 
minutes after
the
 
time
 
appointed
 
for
 
holding
 
the
 
meeting
 
the
 
Noteholders
 
present
 
shall
 
choose
 
one
 
of
their number to be Chair.
5.
 
At
 
any
 
such
 
meeting
 
one
 
or
 
more
 
persons
 
present
 
holding
 
Notes
 
or
 
voting
 
certificates
 
or
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126
being
 
proxies
 
and
 
holding
 
or
 
representing
 
in
 
the
 
aggregate
 
not
 
less
 
than
 
20
 
per
 
cent.
 
in
nominal amount
 
of the
 
Notes
 
for
 
the
 
time
 
being
 
outstanding shall
 
(except for
 
the
 
purpose
of
 
passing an
 
Extraordinary
0010155-0003327 UKO2:
 
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127
Resolution) form a
 
quorum for the
 
transaction of business
 
and no business
 
(other than the
choosing
 
of
 
a
 
Chair)
 
shall
 
be
 
transacted
 
at
 
any
 
meeting
 
unless
 
the
 
requisite
 
quorum
 
be
present
 
at the
 
commencement of
 
business.
 
The quorum
 
at
 
any such
 
meeting for
 
passing
an
 
Extraordinary
 
Resolution
 
shall
 
(subject
 
as
 
provided
 
below)
 
be
 
one
 
or
 
more
 
persons
present holding Notes
 
or voting
 
certificates or
 
being proxies and
 
holding or
 
representing in
the
 
aggregate
 
a
 
clear
 
majority
 
in
 
nominal
 
amount
 
of
 
the
 
Notes
 
for
 
the
 
time
 
being
outstanding
 
PROVIDED
 
THAT
 
at
 
any
 
meeting
 
the
 
business
 
of
 
which
 
includes
 
any
 
of
 
the
following matters
 
(each of
 
which shall
 
only be
 
capable of
 
being
 
effected after
 
having been
approved by Extraordinary Resolution) namely:
(a)
 
modification
 
of
 
the
 
Maturity
 
Date
 
of
 
the
 
Notes
 
or
 
reduction
 
or
 
cancellation
 
of
 
the
nominal amount payable upon maturity; or
(b)
 
reduction or cancellation of the
 
amount payable or modification of the payment
 
date
in
 
respect
 
of
 
any
 
interest
 
in
 
respect
 
of
 
the
 
Notes
 
or
 
variation
 
of
 
the
 
method
 
of
calculating the rate of interest in respect of the Notes; or
(c)
 
reduction of
 
any Minimum
 
Interest Rate
 
and/or Maximum
 
Interest Rate
 
specified in
the applicable Final Terms of any Note; or
(d)
 
modification
 
of
 
the
 
currency
 
in
 
which
 
payments
 
under
 
the
 
Notes
 
and/or
 
Coupons
appertaining thereto are to be made; or
(e)
 
modification of the
 
majority required to pass
 
an Extraordinary Resolution;
 
or
(f)
 
the sanctioning of any
 
such scheme or proposal as
 
is described in paragraph
below; or
(g)
 
alteration of this proviso or
 
the proviso to paragraph
 
below;
the
 
quorum
 
shall
 
be
 
one
 
or
 
more
 
persons
 
present
 
holding
 
Notes
 
or
 
voting
 
certificates
 
or
being
 
proxies
 
and
 
holding
 
or
 
representing
 
in
 
the
 
aggregate
 
not
 
less
 
than
 
75
 
per
 
cent.
 
in
nominal amount
 
of
 
the Notes
 
for the
 
time
 
being outstanding.
 
An
 
Extraordinary Resolution
passed
 
at
 
any
 
meeting
 
of
 
the
 
holders
 
of
 
Notes
 
will
 
be
 
binding
 
on
 
all
 
holders
 
of
 
Notes,
whether or not they are
 
present at the meeting, and
 
on all holders of Coupons appertaining
to such Notes.
6.
 
If
 
within
 
fifteen
 
minutes
 
after
 
the
 
time
 
appointed
 
for
 
any
 
such
 
meeting
 
a
 
quorum
 
is
 
not
present the
 
meeting shall
 
if convened
 
upon the
 
requisition of
 
Noteholders be
 
dissolved.
 
In
any other case it shall stand adjourned to the same day in the next week (or if such day is a
public holiday the next succeeding business day) at the same
 
time and place (except in the
case of
 
a meeting
 
at which
 
an Extraordinary
 
Resolution is
 
to be
 
proposed in
 
which case
 
it
shall stand
 
adjourned for
 
such period
 
being not
 
less than
 
14 days
 
nor more
 
than 42
 
days,
and
 
at
 
such
 
place
 
as may
 
be
 
appointed by
 
the
 
Chair
 
and
 
approved
 
by the
 
Agent)
 
and
 
at
such adjourned meeting one or more persons present holding Notes
 
or voting certificates or
being proxies (whatever
 
the nominal
 
amount of the
 
Notes so
 
held or represented
 
by them)
shall (subject as provided below) form a quorum and shall (subject as provided below) have
power
 
to
 
pass
 
any
 
Extraordinary
 
Resolution
 
or
 
other
 
resolution
 
and
 
to
 
decide
 
upon
 
all
matters
 
which
 
could
 
properly
 
have
 
been
 
dealt
 
with
 
at
 
the
 
meeting
 
from
 
which
 
the
adjournment took
 
place had
 
the
 
requisite
 
quorum
 
been
 
present
 
PROVIDED THAT
 
at
 
any
adjourned
 
meeting
 
the
 
business
 
of
 
which
 
includes
 
any
 
of
 
the
 
matters
 
specified
 
in
 
the
proviso
 
to
 
paragraph
 
above
 
the
 
quorum
 
shall
 
be
 
one
 
or
 
more
 
persons
 
present
 
holding
Notes
 
or
 
voting
 
certificates
 
or
 
being
 
proxies
 
and
 
holding or
 
representing in
 
the
 
aggregate
not
 
less
 
than
 
a
 
clear
 
majority
 
in
 
nominal
 
amount
 
of
 
the
 
Notes
 
for
 
the
 
time
 
being
outstanding.
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7.
 
Notice
 
of
 
any
 
adjourned meeting
 
at
 
which
 
an
 
Extraordinary
 
Resolution
 
is
 
to
 
be
 
submitted
shall
 
be
 
given
 
in
 
the
 
same
 
manner
 
as
 
notice
 
of
 
an
 
original
 
meeting
 
but
 
as
 
if
 
10
 
were
substituted for
 
21 in paragraph
 
above
 
and
 
such
 
notice
 
shall (except
 
in
 
cases
 
where the
proviso
 
to
 
paragraph
 
above
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129
shall apply when it
 
shall state the
 
relevant quorum) state that
 
one or more persons
 
present
holding Notes or
 
voting certificates or being
 
proxies at the
 
adjourned meeting whatever the
nominal amount
 
of the
 
Notes held
 
or represented
 
by them
 
will form
 
a quorum.
 
Subject as
aforesaid it shall not be necessary to give any notice of an adjourned
 
meeting.
8.
 
Except
 
whilst
 
the
 
Notes
 
are
 
in
 
global
 
form
 
and
 
only
 
one
 
proxy
 
is
 
attending
 
the
 
meeting,
every
 
question submitted
 
to
 
a meeting
 
shall be
 
decided in
 
the
 
first
 
instance by
 
a
 
show
 
of
hands.
 
In case
 
of equality
 
of votes
 
the Chair
 
shall both
 
on a
 
show of
 
hands and
 
on a
 
poll
have a casting vote in
 
addition to the vote or votes (if any) to
 
which they may be entitled as
a Noteholder or as a holder of a voting
 
certificate or as a proxy.
9.
 
At
 
any
 
meeting,
 
unless
 
the
 
Notes
 
are
 
in
 
global
 
form
 
and
 
only
 
one
 
proxy
 
is
 
attending
 
the
meeting
 
or
 
a
 
poll
 
is
 
(before
 
or
 
on
 
the
 
declaration
 
of
 
the
 
result
 
of
 
the
 
show
 
of
 
hands)
demanded by
 
the Chair
 
or the
 
Issuer or
 
by one
 
or more
 
persons present
 
holding Notes
 
or
voting certificates
 
or being
 
proxies (whatever
 
the nominal
 
amount of
 
the Notes
 
so held
 
by
them),
 
a
 
declaration
 
by
 
the
 
Chair
 
that
 
a
 
resolution
 
has
 
been
 
carried
 
or
 
carried
 
by
 
a
particular majority or lost or not carried by a particular majority shall be conclusive evidence
of
 
the
 
fact
 
without proof
 
of
 
the
 
number
 
or
 
proportion of
 
the
 
votes recorded
 
in
 
favour
 
of
 
or
against such resolution.
10.
 
Subject
 
to
 
paragraph
 
below,
 
if
 
at
 
any
 
such
 
meeting
 
a
 
poll
 
is
 
so
 
demanded
 
it
 
shall
 
be
taken
 
in
 
such
 
manner
 
and
 
subject
 
as
 
hereinafter
 
provided
 
either
 
at
 
once
 
or
 
after
 
an
adjournment
 
as
 
the
 
Chair
 
directs
 
and
 
the
 
result
 
of
 
such
 
poll
 
shall
 
be
 
deemed
 
to
 
be
 
the
resolution of the meeting at which the poll was demanded as at the date of the taking of the
poll.
 
The
 
demand
 
for
 
a
 
poll
 
shall
 
not
 
prevent
 
the
 
continuance
 
of
 
the
 
meeting
 
for
 
the
transaction of any business other than the motion on which the
 
poll has been demanded.
11.
 
The Chair
 
may with
 
the consent
 
of (and
 
shall if
 
directed by)
 
any such
 
meeting adjourn
 
the
same from time
 
to time and
 
from place to
 
place but no
 
business shall be
 
transacted at any
adjourned meeting
 
except business
 
which might
 
lawfully (but
 
for lack
 
of required
 
quorum)
have been transacted at the meeting from which the adjournment
 
took place.
12.
 
Any
 
poll demanded
 
at
 
any such
 
meeting
 
on the
 
election
 
of
 
a Chair
 
or
 
on any
 
question of
adjournment shall be taken at the meeting without adjournment.
13.
 
Any director
 
or officer
 
of the
 
Issuer and
 
its lawyers
 
may attend
 
and speak
 
at any
 
meeting.
Save as
 
aforesaid, but
 
without prejudice
 
to the
 
proviso to
 
the definition
 
of
outstanding
in
subclause
 
of this
 
Agreement, no
 
person shall be
 
entitled to
 
attend and
 
speak nor
 
shall
any
 
person
 
be
 
entitled
 
to
 
vote
 
at
 
any
 
meeting
 
of
 
the
 
Noteholders
 
or
 
join
 
with
 
others
 
in
requisitioning
 
the
 
convening
 
of
 
such
 
a
 
meeting
 
unless
 
they
 
either
 
produce
 
the
 
Note
 
or
Notes
 
of which
 
they
 
are the
 
holder or
 
a voting
 
certificate or
 
is a
 
proxy.
 
Neither the
 
Issuer
nor any
 
of its
 
Subsidiaries shall be
 
entitled to
 
vote at
 
any meeting in
 
respect of
 
Notes held
by
 
it
 
for the
 
benefit of
 
any such
 
company and
 
no other
 
person shall
 
be entitled
 
to
 
vote
 
at
any
 
meeting
 
in
 
respect
 
of
 
Notes
 
held
 
by
 
it
 
for
 
the
 
benefit
 
of
 
any
 
such
 
company.
 
Nothing
herein
 
contained
 
shall
 
prevent
 
any
 
of
 
the
 
proxies
 
named
 
in
 
any
 
block
 
voting
 
instruction
from being a director, officer or representative of or otherwise connected with the Issuer.
14.
 
Subject as provided in paragraph
 
hereof at any meeting:
(a)
 
on
 
a
 
show of
 
hands
 
every person
 
who is
 
present
 
in
 
person and
 
produces a
 
Note
or
 
voting certificate or is a proxy shall have one vote; and
(b)
 
on a poll every person who
 
is so present shall have one vote
 
in respect of:
(i)
 
in the case of a meeting of the holders of Notes all of which are
denominated in a
 
single currency, each minimum integral amount of such
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currency; and
0010155-0003327 UKO2:
 
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(ii)
 
in the
 
case of
 
a meeting
 
of the
 
holders of
 
Notes denominated
 
in more
 
than
one
 
currency,
 
each
 
€1.00
 
or,
 
in
 
the
 
case
 
of
 
a
 
Note
 
denominated
 
in
 
a
currency
 
other
 
than
 
euro,
 
the
 
equivalent
 
of
 
€1.00
 
in
 
such
 
currency
 
at
 
the
Agent's
 
spot
 
buying
 
rate
 
for
 
the
 
relevant
 
currency
 
against
 
euro
 
at
 
or
 
about
11.00
 
a.m.
 
(London
 
time)
 
on
 
the
 
date
 
of
 
publication
 
of
 
the
 
notice
 
of
 
the
relevant
 
meeting
 
(or
 
of
 
the
 
original
 
meeting
 
of
 
which
 
such
 
meeting
 
is
 
an
adjournment),
or
 
such
 
other
 
amount
 
as
 
the
 
Agent
 
shall
 
in
 
its
 
absolute
 
discretion
 
stipulate
 
in
nominal
 
amount
 
of
 
Notes
 
so
 
produced
 
or
 
represented
 
by
 
the
 
voting
 
certificate
 
so
produced or in respect of which they are a proxy.
Without prejudice to the obligations of the proxies named in any block voting instruction any
person
 
entitled to
 
more than
 
one vote
 
need
 
not use
 
all
 
their
 
votes or
 
cast
 
all the
 
votes to
which they are entitled in the same way.
15.
 
The proxies named in any
 
block voting instruction
 
need not be Noteholders.
16.
 
Each block voting instruction
 
together (if so requested
 
by the Issuer) with proof
 
satisfactory
to the Issuer of
 
its due execution on
 
behalf of the relevant Paying
 
Agent shall be deposited
at such
 
place as the
 
Agent shall approve
 
not less than
 
24 hours before
 
the time appointed
for
 
holding
 
the
 
meeting
 
or
 
adjourned
 
meeting
 
at
 
which
 
the
 
proxies
 
named
 
in
 
the
 
block
voting
 
instruction
 
propose
 
to
 
vote
 
and
 
in
 
default
 
the
 
block
 
voting
 
instruction
 
shall
 
not
 
be
treated as
 
valid unless
 
the Chair
 
of the
 
meeting decides otherwise
 
before such
 
meeting or
adjourned meeting
 
proceeds to
 
business.
 
A certified
 
copy of
 
each block
 
voting instruction
shall be
 
deposited with
 
the Agent
 
before the
 
commencement of
 
the meeting
 
or adjourned
meeting but
 
the Agent
 
shall not
 
thereby be
 
obliged to investigate
 
or be
 
concerned with the
validity of or the authority of the proxies named in any such block voting
 
instruction.
17.
 
Any
 
vote
 
given
 
in
 
accordance
 
with
 
the
 
terms
 
of
 
a
 
block
 
voting
 
instruction
 
shall
 
be
 
valid
notwithstanding the
 
previous revocation
 
or amendment
 
of the
 
block voting
 
instruction or
 
of
any
 
of
 
the
 
Noteholders' instructions
 
pursuant to
 
which
 
it
 
was
 
executed PROVIDED
 
THAT
no intimation in writing of such revocation or amendment shall have been received from
 
the
relevant
 
Paying
 
Agent
 
by
 
the
 
Issuer
 
at
 
its
 
registered
 
office
 
(or
 
such
 
other
 
place
 
as
 
may
have been
 
approved by
 
the Agent
 
for the
 
purpose) by
 
the time
 
being 24
 
hours before
 
the
time
 
appointed
 
for
 
holding
 
the
 
meeting
 
or
 
adjourned
 
meeting
 
at
 
which
 
the
 
block
 
voting
instruction is to be used.
18.
 
A
 
meeting
 
of
 
the
 
Noteholders shall
 
in
 
addition to
 
the
 
powers hereinbefore
 
given
 
have the
following powers exercisable by Extraordinary Resolution
 
(subject to the provisions relating
to quorum contained in paragraphs
 
and
 
above) only, namely:
(a)
 
power to
 
sanction any
 
compromise or
 
arrangement proposed
 
to be
 
made between
the Issuer and the Noteholders and Couponholders or any of
 
them;
(b)
 
power
 
to
 
sanction
 
any
 
abrogation,
 
modification,
 
compromise
 
or
 
arrangement
 
in
respect
 
of
 
the
 
rights
 
of
 
the
 
Noteholders
 
and
 
Couponholders
 
against
 
the
 
Issuer
 
or
against any of its property whether such rights
 
shall arise under this Agreement, the
Notes or the Coupons or otherwise;
(c)
 
power to assent to any modification of the provisions contained in this Agreement or
the
 
Conditions,
 
the
 
Notes,
 
the
 
Coupons
 
or
 
the
 
Deed
 
of
 
Covenant
 
which
 
shall
 
be
proposed by the Issuer;
(d)
 
power
 
to
 
give
 
any
 
authority
 
or
 
sanction
 
which
 
under
 
the
 
provisions
 
of
 
this
Agreement or the Notes is required to be given by Extraordinary
 
Resolution;
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(e)
 
power
 
to
 
appoint
 
any
 
persons
 
(whether
 
Noteholders
 
or
 
not)
 
as
 
a
 
committee
 
or
committees
 
to
 
represent the
 
interests
 
of
 
the
 
Noteholders
 
and
 
to
 
confer upon
 
such
committee
 
or
 
committees
 
any
 
powers
 
or
 
discretions
 
which
 
the
 
Noteholders
 
could
themselves exercise by
 
Extraordinary Resolution;
(f)
 
power to sanction any scheme or proposal for the exchange or sale of the Notes for,
or the
 
conversion of the
 
Notes into
 
or the cancellation
 
of the Notes
 
in consideration
of,
 
shares,
 
stock,
 
notes,
 
bonds,
 
debentures,
 
debenture
 
stock
 
and/or
 
other
obligations
 
and/or
 
securities
 
of
 
the
 
Issuer
 
or
 
any
 
other
 
company
 
formed
 
or
 
to
 
be
formed,
 
or
 
for
 
or
 
into
 
or
 
in
 
consideration
 
of
 
cash,
 
or
 
partly
 
for
 
or
 
into
 
or
 
in
consideration
 
of
 
such
 
shares,
 
stock,
 
notes,
 
bonds,
 
debentures,
 
debenture
 
stock
and/or
 
other
 
obligations
 
and/or
 
securities
 
as
 
aforesaid
 
and
 
partly
 
for
 
or
 
into
 
or
 
in
consideration of cash; and
(g)
 
power
 
to
 
approve
 
the
 
substitution
 
of
 
any
 
entity
 
in
 
place
 
of
 
(i)
 
the
 
Issuer
 
(or
 
any
previous
 
substitute)
 
as
 
the
 
principal
 
debtor
 
in
 
respect
 
of
 
the
 
Notes
 
and
 
the
Coupons.
19.
 
Any
 
resolution
 
(i)
 
passed
 
at
 
a
 
meeting
 
of
 
the
 
Noteholders
 
duly
 
convened
 
and
 
held;
 
(ii)
passed
 
as
 
a
 
resolution
 
in
 
writing
 
or
 
(iii)
 
passed
 
by
 
way
 
of
 
electronic
 
consents
 
given
 
by
Noteholders
 
through
 
the
 
relevant
 
clearing
 
system(s),
 
in
 
accordance
 
with
 
the
 
provision
hereof
 
shall
 
be
 
binding
 
upon
 
all
 
the
 
Noteholders
 
whether
 
present
 
or
 
not
 
present
 
at
 
such
meeting referred to in
 
(i) above and
 
whether or not voting
 
and upon all Couponholders
 
and
each of them
 
shall be bound to
 
give effect thereto accordingly
 
and the passing of
 
any such
resolution
 
shall be
 
conclusive evidence
 
that the
 
circumstances justify
 
the
 
passing thereof.
Notice of the result of the voting
 
on any resolution duly considered by the Noteholders shall
be
 
published in
 
accordance with
 
Condition 12
 
by the
 
Issuer
 
within 14
 
days
 
of
 
such result
being known PROVIDED THAT
 
the non-publication of such
 
notice shall not invalidate
 
such
resolution.
20.
 
The expression
Extraordinary
 
Resolution
when used
 
in this
 
Agreement or
 
the Conditions
means
(a)
 
a
 
resolution
 
passed
 
at
 
a
 
meeting
 
of
 
the
 
Noteholders
 
duly
 
convened
 
and
 
held
 
in
accordance with the provisions herein contained by a majority consisting of not less than 75
per cent. of the
 
persons voting thereat upon a show
 
of hands or if
 
a poll be duly demanded
then by a majority consisting of not less
 
than 75 per cent. of the votes given
 
on such poll
 
or
(b) a resolution in writing signed
 
by or
 
on behalf of the holders of
 
not less than 75 per cent.
in nominal
 
amount
 
of the
 
Notes for
 
the time
 
being outstanding,
 
which resolution
 
in writing
may be contained in
 
one document or
 
in several documents in
 
similar form each signed
 
by
or
 
on
 
behalf
 
of
 
one
 
or
 
more
 
of
 
the
 
Noteholders or
 
(c)
 
consent
 
given
 
by
 
way
 
of
 
electronic
consents through the
 
relevant clearing system(s)
 
(in a form
 
satisfactory to the
 
Agent) by or
on behalf of the holders of not less than 75 per cent. in nominal amount of the Notes for the
time being outstanding.
21.
 
Minutes
 
of
 
all
 
resolutions
 
and
 
proceedings
 
at
 
every
 
such
 
meeting
 
as
 
aforesaid
 
shall
 
be
made
 
and duly
 
entered in
 
books to
 
be from
 
time to
 
time
 
provided for
 
that
 
purpose by
 
the
Issuer
 
and
 
any
 
such
 
Minutes
 
as
 
aforesaid
 
if
 
purporting
 
to
 
be
 
signed
 
by
 
the
 
Chair
 
of
 
the
meeting
 
at
 
which
 
such
 
resolutions
 
were
 
passed
 
or
 
proceedings
 
had
 
shall
 
be
 
conclusive
evidence
 
of
 
the
 
matters
 
therein
 
contained
 
and
 
until
 
the
 
contrary
 
is
 
proved
 
every
 
such
meeting in
 
respect of
 
the proceedings
 
of which Minutes
 
have been made
 
shall be
 
deemed
to
 
have
 
been
 
duly
 
held
 
and
 
convened
 
and
 
all
 
resolutions
 
passed
 
or
 
proceedings
 
had
thereat to have been duly passed or had.
22.
 
Subject
 
to
 
all
 
other
 
provisions contained
 
herein the
 
Agent may
 
without the
 
consent of
 
the
Issuer,
 
the Noteholders
 
or the
 
Couponholders prescribe
 
such further
 
regulations regarding
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the requisitioning and/or the
 
holding of meetings of Noteholders
 
and attendance and voting
thereat
 
as
 
the
 
Agent
 
may
 
in
 
its
 
sole
 
discretion
 
think
 
fit
 
(including,
 
without
 
limitation,
 
the
holding of
 
meetings by
 
conference call,
 
including by
 
use of
 
a videoconference
 
platform in
circumstances where it may be impractical or inadvisable to hold physical
 
meetings).
0010155-0003327 UKO2:
 
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SCHEDULE 5
FORM OF PUT NOTICE
for Notes in definitive form
EQUINOR ASA
[
title of relevant Series
 
of Notes
]
By depositing this duly completed
 
Notice with any Paying Agent for
 
the above Series of Notes
 
(the
Notes
)
 
the
 
undersigned holder
 
of
 
such
 
Notes surrendered
 
with this
 
Notice and
 
referred to
 
below
irrevocably exercises its option to have
 
such Notes redeemed in accordance with Condition
 
5(
f
) on
[redemption date].
This Notice relates to Notes
 
in the aggregate nominal
 
amount of
.............. bearing the following serial numbers:
................................................................
................................................................
................................................................
If the
 
Notes referred
 
to above
 
are to
 
be returned
 
(1) to
 
the
 
undersigned under
 
subclause
 
of
the Agency Agreement, they should be returned by post to:
.........................
.........................
.........................
Payment Instructions
Please make
 
payment in
 
respect
 
of the
 
above-mentioned Notes
 
by [cheque
 
posted to
 
the
 
above
address/transfer to the following bank account] (2):
Bank:
 
................................
Branch Address:
 
................................
Branch Code:
 
................................
Account Number:
 
................................
Signature of holder:
 
................................
Duly authorised on behalf of [
]
[To
 
be completed by
 
recipient Paying
Agent]
Details of missing unmatured
 
Coupons
 
....................
 
(3)
Received by:
 
.........................
0010155-0003327 UKO2:
 
2004375908.9
135
[Signature and stamp of
 
Paying Agent]
At its office at:
 
.................................
On:
 
......................................
Notes
(1)
 
The Agency Agreement provides that Notes so returned will be sent by post, uninsured and
at the
 
risk of the
 
Noteholder, unless
 
the Noteholder otherwise
 
requests and pays
 
the costs
of such
 
insurance to
 
the relevant
 
Paying Agent
 
at the
 
time of
 
depositing the
 
Note referred
to above.
(2)
 
Delete as applicable.
(3)
 
Only relevant for Fixed
 
Rate Notes in definitive
 
form.
N.B.
 
The
 
Paying
 
Agent
 
with
 
whom
 
the
 
above-mentioned
 
Notes
 
are
 
deposited
 
will
 
not
 
in
 
any
circumstances
 
be
 
liable
 
to
 
the
 
depositing
 
Noteholder
 
or
 
any
 
other
 
person
 
for
 
any
 
loss
 
or
damage
 
arising
 
from
 
any
 
act,
 
default
 
or
 
omission
 
of
 
such
 
Paying
 
Agent
 
in
 
relation
 
to
 
the
said Notes
 
or any
 
of them
 
unless such
 
loss or
 
damage was
 
caused by
 
the fraud
 
or gross
negligence of such Paying Agent or its directors, officers or employees.
This
 
Put
 
Notice
 
is
 
not
 
valid
 
unless
 
all
 
of
 
the
 
paragraphs
 
requiring
 
completion
 
are
 
duly
completed.
 
Once
 
validly
 
given
 
this
 
Put
 
Notice
 
is
 
irrevocable
 
except
 
in
 
the
circumstances
 
set
 
out
 
in subclause
 
of the Agency Agreement.
0010155-0003327 UKO2:
 
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SCHEDULE 6
FORM OF
 
DEED POLL
This Deed
 
Poll is
 
made on
 
[
 
] by
 
[
name of
 
existing issuer
] as
 
existing issuer
 
(in its
 
capacity as
existing
 
issuer
 
of
 
the
 
Notes
 
(as
 
defined
 
below),
 
the
Existing
 
Issuer
),
 
a
 
company
 
incorporated
in
 
[
 
],
 
[and] [
name
 
of
 
Substitute
]
 
as
 
the
 
substitute
 
of
 
the
 
Existing
 
Issuer
 
(the
Substitute
),
 
a
company
 
incorporated
 
in
 
[
 
]
 
[and
 
Equinor
 
ASA
 
[and
 
Equinor
 
Energy
 
AS]
 
as
 
guarantor[s]
 
(in
[its][their]
 
capacity
 
as
 
guarantor[s],
 
the
Guarantor[s]
),
 
[a
 
company][companies]
 
incorporated
 
in
The Kingdom of Norway].
(A)
 
The
 
Existing
 
Issuer
 
has
 
entered
 
into
 
a
 
Programme
 
Agreement
 
dated
 
9
 
May
 
2022
 
(the
Programme
 
Agreement
which
 
expression
 
includes
 
the
 
same
 
as
 
it
 
may
 
be
 
amended,
supplemented
 
or
 
restated from
 
time
 
to
 
time)
 
with the
 
Dealers
 
named therein
 
under
 
which
the Existing Issuer has issued and
 
has outstanding Euro Medium Term Notes (
Notes
).
(B)
 
The
 
Notes
 
have
 
been
 
issued
 
subject
 
to
 
and
 
have
 
the
 
benefit
 
of
 
an
 
Agency
 
Agreement
dated 9 May
 
2022 (the
Agency Agreement
which expression includes the same
 
as it may
be amended,
 
supplemented or
 
restated from
 
time to
 
time) and
 
entered into
 
between,
inter
alios
,
 
the
 
Existing
 
Issuer,
 
The
 
Bank
 
of
 
New
 
York
 
Mellon,
 
London
 
Branch
 
as
 
Agent
 
(the
Agent
which expression shall include
 
its successor or
 
successors for the
 
time being under
the Agency Agreement) and the other parties named therein.
(C)
 
The
 
Existing
 
Issuer
 
has
 
executed
 
a
 
Deed
 
of
 
Covenant
 
dated
 
13
 
May
 
2020
 
(the
Deed
 
of
Covenant
,
 
which
 
expression includes
 
the
 
same as
 
it
 
may
 
be
 
amended, supplemented
 
or
restated from
 
time to
 
time) relating
 
to Global
 
Notes (as
 
defined in
 
the Agency
 
Agreement)
issued by the Existing Issuer pursuant to the Programme Agreement.
(D)
 
It
 
has
 
been
 
proposed
 
that
 
in
 
respect
 
of
 
the
 
Notes
 
there
 
will
 
be
 
a
 
substitution
 
of
 
the
Substitute
 
for
 
the
 
Existing
 
Issuer
 
as
 
the
 
issuer
 
of
 
the
 
Notes.
 
Expressions
 
defined
 
in
 
the
Agency
 
Agreement
 
have
 
the
 
same
 
meaning
 
in
 
this
 
Deed
 
unless
 
the
 
context
 
requires
otherwise.
(E)
 
References
 
herein
 
to
Notes
include
 
any
Underlying
 
Notes
(as
 
defined
 
in
 
the
 
Deed
 
of
Covenant).
 
References
 
herein
 
to
Coupons
are
 
to
 
Coupons
 
relating
 
to
 
the
 
Notes.
References
 
herein
 
to
Holder
means
 
any
 
Noteholder,
 
Couponholder
 
or,
 
in
 
relation
 
to
 
any
Underlying Notes, any Relevant Account Holder.
THIS DEED WITNESSES
as follows:
1.
 
The Substitute agrees that, with
 
effect from and
 
including the first date on
 
which notice has
been given by the Existing Issuer pursuant to Condition 14 and all
 
the other requirements of
such Condition have been met (the
Effective Date
), it shall be deemed to be
the Issuer
for
all purposes in respect of the Notes
 
and any Coupons and accordingly it shall be entitled
 
to
all the rights, and
 
subject to all the liabilities, on
 
the part of the
 
Existing Issuer contained in
them.
2.
 
With effect from and including
 
the Effective Date:
(a)
 
the
 
Existing Issuer
 
shall
 
be
 
released
 
from
 
all
 
its
 
liabilities, in
 
its
 
capacity as
issuer
 
of
 
the Notes, contained in the Notes and any Coupons; and
(b)
 
the Terms and Conditions of the Notes (the
Conditions
) shall be amended as
 
follows:
(i)
 
all references to
the Kingdom of Norway
[(or, as the case may be, the
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jurisdiction of
 
incorporation
 
or
 
residence
 
for
 
tax
 
purposes
 
of
 
the
preceding
 
substituted
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company)] in Condition 5(b)
 
shall, in respect of
 
payments to be made
 
by the
Substitute
 
(but
 
not
 
in
 
respect
 
of
 
payments
 
to
 
be
 
made
 
by
 
[[(A)]
 
the
 
New
Guarantor
 
(as
 
defined
 
below)
 
][[or
 
(B)]
 
the
 
Guarantor[s])]
 
under
 
this
 
Deed
Poll), be
 
replaced
 
by references to
 
"[
jurisdiction of
 
a country
 
of residence of
the Substitute for tax purposes and/or, if different, of its incorporation
]"; and
(ii)
 
all
 
references
 
to
the
 
Kingdom
 
of
 
Norway
[(or,
 
as
 
the
 
case
 
may
 
be,
 
the
jurisdiction
 
of
 
incorporation
 
or
 
residence
 
for
 
tax
 
purposes
 
of
 
the
 
preceding
substituted
 
company)]
 
in
 
Condition
 
6
 
shall,
 
in
 
respect
 
of
 
payments
 
to
 
be
made by the
 
Substitute (but not
 
in respect of
 
payments to be
 
made by [[(A)]
the New Guarantor (as
 
defined below) ][[or (B)]
 
the Guarantor[s])] under this
Deed
 
Poll),
 
be
 
replaced
 
by
 
references
 
to
 
"[
jurisdiction
 
of
 
a
 
country
 
of
residence
 
of
 
the
 
Substitute
 
for
 
tax
 
purposes
 
and/or,
 
if
 
different,
 
of
 
its
incorporation
]".
3.
 
(a)
 
The [Existing Issuer
 
(in such capacity,
 
the
New Guarantor
)[ and the]
 
Guarantor[s][,
subject
 
(in
 
the
 
case
 
of
 
Equinor
 
Energy
 
AS)
 
to
 
Condition
 
[2(c)]
 
(
Termination
 
of
 
the
Guarantee
) and clause 3(g) below,] unconditionally and irrevocably guarantee[s] [on
a joint and several basis] that, if for any reason the Substitute does not pay any sum
payable by it
 
under any Note or
 
Coupon (whether or not
 
attached to it) or
 
this Deed
on
 
the
 
date
 
specified
 
for
 
such
 
payment
 
(whether
 
on
 
the
 
normal
 
due
 
date,
 
on
acceleration
 
or
 
otherwise),
 
[the
 
New
 
Guarantor
 
][or]
 
the
 
Guarantor[s]
 
will
 
pay
 
that
sum
 
in
 
the
 
currency
 
in
 
which
 
it
 
is
 
payable
 
under
 
such
 
Note
 
to
 
the
 
Holder
 
on
 
that
date on
 
demand to
 
[either][ the
 
New Guarantor
 
at [
]][ or
 
]the Guarantor[s] at [
 
]].
(b)
 
As
 
between [the
 
New
 
Guarantor][, ][the
 
Guarantor[s]] and
 
each
 
Holder
 
but
 
without
effecting
 
the
 
Substitute's
 
obligations,
 
[each
 
of][
 
the
 
New
 
Guarantor
 
][and
 
][the
Guarantor[s]]
 
will
 
be
 
[jointly
 
and
 
severally]
 
liable
 
under
 
this
 
Deed
 
as
 
if
 
it
 
were
 
the
sole
 
principal
 
debtor
 
and
 
not
 
merely
 
a
 
surety.
 
Accordingly,
 
[each
 
of][
 
the
 
New
Guarantor][and][
 
the
 
Guarantor[s]]
 
will
 
not
 
be
 
discharged,
 
nor
 
will
 
its
 
liability
 
be
affected,
 
by anything
 
which would
 
not
 
discharge it
 
or
 
affect
 
is liability
 
if
 
it were
 
the
sole
 
principal
 
debtor
 
(including
 
(i)
 
any
 
time,
 
indulgence,
 
concession,
 
waiver
 
or
consent at any time given to the Substitute or
 
any other person, (ii)
 
any amendment
or
 
supplement to
 
any
 
of
 
the
 
Conditions
 
or
 
to
 
this
 
Deed
 
or
 
to
 
any
 
security
 
or
 
other
guarantee or indemnity, (iii) the making or absence of any demand on the Substitute
or any other person for payment, (iv)
 
the enforcement or absence of enforcement of
any
 
Note
 
or
 
any
 
Coupon
 
or
 
this
 
Deed
 
or
 
of
 
any
 
security
 
or
 
other
 
guarantee
 
or
indemnity,
 
(v)
 
the
 
taking,
 
existence
 
or
 
release
 
of
 
any
 
security,
 
guarantee
 
or
indemnity,
 
(vi)
 
the
 
winding-up,
 
dissolution,
 
amalgamation,
 
reconstruction
 
or
reorganisation of the Substitute or
 
any other person or (vii) the
 
illegality, invalidity or
unenforceability of or
 
any defect in
 
any provision of
 
any Note or
 
any Coupon or
 
this
Deed or any of the Substitute's obligations under any of them).
(c)
 
The
 
[New
 
Guarantor's
 
][and,
 
subject
 
(in
 
the
 
case
 
of
 
Equinor
 
Energy
 
AS)
 
to
Condition
 
[2(c)]
 
(
Termination
 
of
 
Guarantee
)
 
and
 
clause
 
3(g)
 
below,
 
the
Guarantor[s]'[s]
 
respective]
 
obligations
 
under
 
this
 
Deed
 
are
 
and
 
will
 
remain
 
in
 
full
force
 
and effect
 
by way
 
of
 
continuing security
 
until no
 
sum
 
remains payable
 
under
the Notes or any
 
Coupons or this Deed. Furthermore, these
 
obligations of [each of][
the
 
New
 
Guarantor
 
][and
 
][the
 
Guarantor[s]]
 
are
 
additional
 
to,
 
and
 
not
 
instead
 
of,
any
 
security
 
or
 
other
 
guarantee
 
or
 
indemnity
 
at
 
any
 
time
 
existing
 
in
 
favour
 
of
 
any
person,
 
whether
 
from
 
[the
 
New
 
Guarantor][,
 
][the
 
Guarantor[s]]
 
or
 
otherwise,
 
and
may
 
be
 
enforced
 
without first
 
having
 
recourse to
 
the
 
Substitute,
 
any other
 
person,
any
 
security
 
or
 
any
 
other
 
guarantee
 
or
 
indemnity.
 
[The][Each
 
of
 
the][
 
New
Guarantor
 
][and][
 
the
 
Guarantor[s]]
 
irrevocably
 
waive[s]
 
all
 
notices
 
and
 
demands
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whatsoever.
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(d)
 
So long
 
as any
 
sum remains
 
payable under
 
any Note
 
or any
 
Coupon or
 
this Deed
no right of the [New Guarantor ][or ][the Guarantor[s]], by reason of the performance
of any
 
of [its][their]
 
obligations under this
 
Deed, to
 
be indemnified
 
by the
 
Substitute
or to take the benefit of or enforce any security or other guarantee or indemnity shall
be exercised or enforced.
(e)
 
[The][Each of
 
the][ New
 
Guarantor ][and
 
the] Guarantor[s]]
 
shall on
 
demand [jointly
and
 
severally]
 
indemnify
 
the
 
relevant
 
Holder
 
against
 
any
 
cost,
 
loss,
 
expense
 
or
liability sustained
 
or
 
incurred by
 
it
 
(other than
 
value added
 
tax or
 
similar tax
 
to the
extent
 
recoverable
 
by
 
the
 
relevant
 
Holder)
 
as
 
a
 
result
 
of
 
it
 
being
 
required
 
for
 
any
reason (including any bankruptcy,
 
insolvency,
 
winding-up, dissolution, or similar law
of any jurisdiction)
 
to refund all
 
or part
 
of any amount
 
received or recovered
 
by it in
respect of
 
any sum
 
payable by
 
the
 
Substitute under
 
any
 
relevant
 
Note
 
or
 
Coupon
or
 
this
 
Deed
 
and
 
[each
 
of
 
][the
 
New
 
Guarantor
 
][and
][the Guarantor[s]] shall in
 
any event pay
 
to it on
 
demand the amount
 
as refunded by
it.
(f)
 
As
 
separate,
 
independent
 
and
 
alternative
 
stipulations,
 
[each
 
of
 
][the
 
New
Guarantor
 
][and
][the
 
Guarantor[s]]
 
unconditionally
 
and
 
irrevocably
 
agrees[,
 
on
 
a
 
joint
 
and
 
several
basis]: (i)
 
that any
 
sum which,
 
although expressed
 
to
 
be payable
 
by the
 
Substitute
under any
 
Note or
 
any Coupon or
 
this Deed, is
 
for any
 
reason (whether or
 
not now
existing
 
and
 
whether or
 
not
 
now
 
known
 
or
 
becoming known
 
to
 
the
 
Substitute, [the
New
 
Guarantor][
 
the
 
Guarantor[s]]
 
or
 
any
 
Noteholder
 
or
 
Couponholder)
 
not
recoverable from [either [of ]][the New
 
Guarantor ][or
][the
 
Guarantor[s]]
 
on
 
the
 
basis
 
of
 
a
 
guarantee
 
shall
 
nevertheless
 
be
 
recoverable
from
 
it
 
if
 
it
 
were
 
the
 
sole
 
principal
 
debtor
 
and
 
shall
 
be
 
paid
 
by
 
it
 
to
 
the
 
relevant
Holder on demand
 
and
(ii) as
 
a primary
 
obligation to
 
indemnify each
 
Holder against
 
any loss
 
suffered by
 
it
as a result of any sum expressed to
 
be payable by the Substitute under any Note or
any Coupon
 
or this
 
Deed not
 
being paid
 
by the
 
time, on
 
the date
 
and otherwise
 
in
the manner
 
specified therein or
 
any payment obligation
 
of the
 
Substitute under any
Note or any Coupon or this Deed being or becoming
 
void, voidable or unenforceable
for
 
any
 
reason
 
(whether
 
or
 
not
 
now
 
existing
 
and
 
whether
 
or
 
not
 
now
 
known
 
or
becoming
 
known
 
to
 
the
 
Substitute,
 
[the
 
New
 
Guarantor][,
 
the
 
Guarantor[s]]
 
or
 
any
Noteholder or
 
Couponholder), the
 
amount of
 
that loss
 
being the
 
amount expressed
to be payable by the Substitute in respect of the relevant sum.
(g)
 
[The release
 
of Equinor
 
Energy AS
 
in accordance
 
with Condition
 
2(c) (
Termination
of Guarantee
) from its
 
obligations under this
 
Deed Poll will take
 
effect automatically
unconditionally,
 
without prejudice
 
to
 
any obligations
 
which may
 
have accrued
 
prior
to that time, without the need for any further act or thing to be done.]
4.
 
All
 
payments
 
made
 
by
 
[either
 
[of
 
]][the
 
New
 
Guarantor
 
][or
 
][the
 
Guarantor[s]]
 
under
 
this
Deed
 
shall be made free
 
and clear of, and
 
without withholding or deduction for,
 
any taxes,
duties, assessments or governmental charges (
Taxes
) of whatever nature
 
imposed, levied,
collected, withheld or assessed by or within the Kingdom of Norway or any authority therein
or thereof
 
having power to
 
tax, unless
 
such withholding or
 
deduction is
 
required by
 
law.
 
In
that
 
event
 
[either [of]][the
 
New
 
Guarantor ][or
 
][the
 
Guarantor[s]] shall
 
pay such
 
additional
amounts as will result in receipt by the Noteholders and Couponholders of
 
such amounts as
would
 
have
 
been
 
received
 
by
 
them
 
had
 
no
 
such
 
withholding
 
or
 
deduction
 
been
 
required,
except that no such additional amounts shall be
 
payable in respect of any Note or Coupon:
(a)
 
to,
 
or
 
to
 
a
 
third
 
party
 
on
 
behalf
 
of,
 
a
 
Holder
 
who
 
presented
 
the
 
relevant
 
Note
 
or
Coupon for payment in the Kingdom of Norway;
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(b)
 
to,
 
or
 
to
 
a
 
third
 
party
 
on
 
behalf
 
of,
 
a
 
Holder
 
who
 
is
 
liable
 
(or
 
where
 
the
 
beneficial
owner is liable) to such Taxes
 
by reason of the Holder having some connection with
the Kingdom of Norway other than the mere holding of the Note
 
or Coupon;
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(c)
 
to,
 
or
 
to
 
a
 
third
 
party
 
on
 
behalf
 
of,
 
a
 
Holder
 
who
 
presented
 
the
 
relevant
 
Note
 
or
Coupon for
 
payment more
 
than 30
 
days after
 
the Relevant
 
Date (as
 
defined in
 
the
Conditions) except
 
to the
 
extent that
 
such Holder
 
would have
 
been entitled
 
to such
additional amounts on presenting the same for payment on such
 
thirtieth day;
(d)
 
on
 
account
 
of
 
any
 
Taxes
 
that
 
are
 
payable
 
pursuant
 
to
 
the
 
Norwegian
 
Tax
 
Act
section
 
10-80 on
 
payments to
 
related
 
companies or
 
undertakings (as
 
such term
 
is
defined in the Norwegian Tax
 
Act section 10-82) tax resident in a low-tax jurisdiction
(as such term is defined in the Norwegian Tax Act section 10-63); or
(e)
 
as a result of any FATCA Withholding (as defined in the Agency
 
Agreement).
5.
 
The Conditions shall apply,
 
where the context so admits, with any
 
necessary consequential
modifications,
 
to
 
[the
 
New
 
Guarantor
 
][,
 
][the
 
Guarantor[s]]
 
and
 
to
 
[its][their
 
respective]
obligations under this Deed.
 
For the avoidance of doubt:
(a)
 
in Condition
 
2(b) (
Status of
 
Guarantee
) the
 
payment obligations shall
 
include those
of [the New Guarantor ][and ][the Guarantor[s]] under this Deed;
(b)
 
[Condition
 
2(c)
 
(
Termination
 
of
 
Guarantee
)
 
shall
 
apply,
mutatis
 
mutandis
,
 
to
 
the
obligations
 
of
 
Equinor
 
Energy
 
AS
 
(but
 
not,
 
for
 
the
 
avoidance
 
of
 
doubt,
 
the
[New][other] Guarantor) under clause 3 of this Deed;]
(c)
 
in Condition 5(b) (
Redemption for Tax Reasons
):
(i)
 
references
 
to
 
"the
 
Guarantee"
 
shall
 
be
 
replaced
 
by
 
references
 
to
 
the
obligations of
 
the
 
[New Guarantor
 
][[and ][the
 
Guarantor[s][, as
 
applicable,]
under clause 3 of this Deed; and
(ii)
 
references to
 
"the Guarantor"
 
shall be
 
replaced by
 
references to
 
"[each of][
the New Guarantor ][and ][the Guarantor[s]]";
(d)
 
Condition 5(h)
 
(
Purchases
) shall
 
apply,
mutatis mutandis,
to [the
 
New Guarantor
 
][,
][the
 
Guarantor[s]] and
 
any Notes
 
so purchased
 
shall not
 
entitle the
 
holder to
 
vote
at, or
 
attend, or
 
be counted towards
 
the quorum at
 
meetings of
 
the Noteholders
 
for
such Notes;
(e)
 
Condition 8 (
Events of Default
):
(i)
 
references
 
to
 
the
 
Issuer
 
in
 
subclause
 
(d)
 
(
Winding-up
),
 
shall
 
include
 
a
reference to [the New Guarantor][ and ][the Guarantor[s]];
(ii)
 
there
 
shall
 
be
 
an
 
additional
 
Event
 
of
 
Default
 
if
 
the
 
Substitute
 
ceases
 
to
be wholly-owned and controlled by Equinor ASA; and
(iii)
 
there
 
shall
 
be
 
an
 
additional
 
Event
 
of
 
Default
 
if
 
the
 
obligations
 
of
 
[the
 
New
Guarantor ][or
 
][either of
 
][the Guarantor[s]]
 
under this
 
Deed are
 
not (or
 
are
claimed by [the New Guarantor ][or ][either of ][the Guarantor[s]] not to be) in
full force and effect; and
(f)
 
in
 
Condition
 
13
 
(
Meetings
 
of
 
Noteholders,
 
Modification
 
and
 
Waiver
)
 
an
 
extra
category
 
shall
 
be
 
added
 
to
 
the
 
proposals
 
for
 
which
 
a
 
special
 
quorum
 
is
 
required,
namely
 
a
 
proposal
 
to
 
modify
 
or
 
cancel
 
the
 
obligations
 
of
 
[either
 
[of]][
 
the
 
New
Guarantor][ or ][the Guarantor[s]] under this Deed.
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6.
 
The Substitute[, / and][ the New Guarantor ][and][ the Guarantor[s]] agree that the benefit of
the undertakings
 
and the
 
covenants binding
 
upon them
 
contained in
 
this Deed
 
shall be
 
for
the benefit of
 
each and every
 
Holder and each Holder
 
shall be entitled
 
severally to enforce
such
 
obligations
 
against
 
the
 
Substitute[,
 
/
 
and][
 
the
 
New
 
Guarantor
 
][and
 
][
 
the
Guarantor[s]].
7.
 
This Deed
 
shall be
 
deposited with
 
and held
 
to the
 
exclusion of
 
the Substitute[,
 
/ and][
 
the
New
 
Guarantor
 
][and
 
][the
 
Guarantor[s]]
 
by
 
the
 
Agent
 
at
 
its
 
specified
 
office
 
for
 
the
 
time
being
 
under
 
the
 
Conditions
 
and
 
the
 
Substitute[,
 
/
 
and][
 
the
 
New
 
Guarantor
 
][and][
 
the
Guarantor[s]] hereby
 
acknowledge the right
 
of every
 
Noteholder to production
 
of this
 
Deed
and,
 
upon
 
request
 
and
 
payment
 
of
 
the
 
expenses
 
incurred
 
in
 
connection
 
therewith,
 
to
 
the
production of a copy hereof certified by the Agent to be a true and
 
complete copy.
8.
 
This Deed
 
may only
 
be amended
 
in the
 
same way
 
as the
 
other Conditions
 
are capable
 
of
amendment under
 
of the
 
Agency Agreement
 
and any
 
such amendment
 
of this
Deed
 
will
 
constitute
 
one
 
of
 
the
 
proposals
 
specified
 
in
 
Condition
 
13
 
(
Meetings
 
of
Noteholders, Modification and Waiver
) to which special quorum provisions apply.
9.
 
The
 
Deed
 
and
 
any
 
non-contractual
 
obligations
 
arising
 
out
 
of
 
or
 
in
 
connection
 
with
 
it
 
are
governed
 
by, and shall be construed in accordance with, English law.
10.
 
The Courts of England are to
 
have jurisdiction to settle any disputes which may arise
 
out of
or in
 
connection with this
 
Deed and accordingly
 
any legal action
 
or proceedings arising out
of or
 
in connection
 
with this
 
Deed (
Proceedings
) may
 
be brought
 
in such
 
courts.
 
Each of
the
 
Substitute[, /
 
and][
 
the
 
New
 
Guarantor
 
][and][
 
the
 
Guarantor[s]]
 
irrevocably
 
submits
 
to
the
 
jurisdiction
 
of
 
such
 
courts
 
and
 
waives
 
any
 
objection
 
to
 
Proceedings
 
in
 
such
 
courts
whether on the
 
ground of venue
 
or on the
 
ground that the
 
Proceedings have been
 
brought
in an inconvenient
 
forum.
 
This submission is made
 
for the benefit
 
of each Holder and
 
shall
not
 
limit
 
the
 
right
 
of
 
any
 
of
 
them
 
to
 
take
 
Proceedings
 
in
 
any
 
other
 
court
 
of
 
competent
jurisdiction
 
nor
 
shall
 
the
 
taking
 
of
 
Proceedings
 
in
 
one
 
or
 
more
 
jurisdictions
 
preclude
 
the
taking of Proceedings in any other jurisdiction (whether concurrently
 
or not).
11.
 
No
 
rights
 
are
 
conferred
 
on
 
any
 
person
 
under
 
the
 
Contracts
 
(Rights
 
of
 
Third
 
Parties)
 
Act
1999 to
 
enforce any
 
term of
 
this Deed,
 
but this
 
does not
 
affect any
 
right or
 
remedy of
 
any
person which
 
exists or is available apart from that Act.
12.
 
Each
 
of
 
the
 
Substitute[,
 
/
 
and][
 
the
 
New
 
Guarantor
 
][and][
 
the
 
Guarantor[s]]
 
irrevocably
appoints
 
[
 
]
 
of
 
[
 
]
 
as
 
its
 
agent
 
in
 
England
 
to
 
receive
 
service
 
of
 
process
 
in
respect
 
of
 
any Proceedings
 
in England.
 
If for
 
any reason
 
it does
 
not have
 
such an
 
agent
for
 
service
 
of
 
process,
 
the
 
Substitute[,
 
/
 
or][
 
the
 
New
 
Guarantor
 
][or
 
][the
 
[relevant]
Guarantor], as the case may be,
 
will promptly appoint a substitute process agent
 
and notify
the
 
Noteholders
 
of
 
such
 
appointment
 
in
 
accordance
 
with
 
the
 
Conditions.
 
Nothing
 
herein
shall affect the right to serve process in any other manner permitted by law.
IN WITNESS
whereof this Deed has been
 
executed as a deed poll on
 
the date stated at the
beginning.
EXECUTED
as a
DEED
)
by EQUINOR ASA and signed
 
)
and delivered as a deed on
 
its
 
)
behalf by
 
)
an authorised representative of
 
the company
 
)
0010155-0003327 UKO2:
 
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EXECUTED
as a
DEED
)
by [
Substitute
] and signed
 
)
and delivered as a deed on
 
its
 
)
behalf by
 
)
an authorised representative of
 
the company
 
)
[
EXECUTED
as a
DEED
)
by EQUINOR ENERGY AS and signed
)
and signed
 
)
and delivered as a deed on
 
its
 
)
behalf by
 
)
an authorised representative of
 
the company
 
)]
0010155-0003327 UKO2:
 
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SCHEDULE 7
FORM OF ISSUER – ICSDs
 
AGREEMENT
Agreement to be sent to
 
both:
Euroclear Bank
 
SA/NV
New Issues Department
1 Boulevard du
 
Roi Albert
II B-1210 Brussels,
Belgium
newissues.issuerageement@euroclear.
com Fax: +32 (0) 2 224 1421
and
 
Clearstream Banking
SA New Issues
Department 42
Avenue J.F. Kennedy
L-1855 Luxembourg
issueragreements@clearstream.co
m Fax: +44 (0)207 862 7005
PROGRAMME FORM
AGREEMENT ENTERED INTO THIS
 
10 MAY,
 
OF 2019, AMONG:
Name of issuer:
 
Equinor ASA
Address of issuer:
 
Forusbeen 50, N-4035 Stavanger, Norway
 
(the
Issuer
); and
Euroclear Bank SA/NV of 1 Boulevard du
 
Roi Albert II, B-1210 Brussels, Belgium and
 
Clearstream
Banking
 
SA
 
of
 
42
 
Avenue
 
J.F.
 
Kennedy,
 
L-1855
 
Luxembourg
 
(each
 
a
Relevant
 
Clearing
System
).
Subject: Acceptance of:
Programme Name:
Equinor ASA €20,000,000,000
 
Euro Medium Term Note Programme
Programme Number: 4138
This agreement
 
sets forth
 
the understanding
 
of the
 
parties with
 
respect to
 
securities to
 
be issued,
as
 
applicable, in
 
(i)
 
bearer
 
New
 
Global
 
Note
 
form
 
(
NGN
 
Securities
)
 
or
 
(ii)
 
registered
 
form
 
under
the
 
New
 
Safekeeping
 
Structure
 
(
NSS
 
Securities
)
 
under
 
the
 
above-captioned
 
programme
 
(the
Securities
)
 
that
 
the
 
Issuer
 
may
 
request
 
be
 
made
 
eligible
 
for
 
settlement
 
with
 
Euroclear
 
Bank
SA/NV and Clearstream Banking
 
SA (the
ICSDs
).
In order to allow the ICSDs to accept the Securities as eligible for settlement with the ICSDs and to
properly service the
 
Securities, the Issuer
 
hereby represents and
 
warrants to
 
the ICSDs that
 
in all
matters relating to
 
the Securities it will, and
 
it will require any agent
 
appointed by it to, comply with
the requirements for the Securities set out herein.
1.
 
The ICSDs hereby agree that:
(a)
 
with respect
 
to the
 
issue outstanding
 
amount (
IOA
) of
 
the Securities,
 
each of
 
them will
 
(in
the
 
case
 
of
 
NGN
 
Securities)
 
maintain
 
their
 
respective
 
portion
 
of
 
the
 
IOA
 
through
 
their
records;
 
will
 
(in
 
the
 
case
 
of
 
NSS
 
Securities)
 
reflect
 
through
 
their
 
records
 
their
 
respective
portion
 
of
 
the
 
IOA
 
as
 
maintained
 
by
 
the
 
NSS
 
securities'
 
register;
 
will
 
undertake
 
daily
reconciliations of
 
such amounts
 
with
 
each other;
 
and
 
will ensure
 
on
 
a
 
daily basis
 
that
 
the
aggregate total of their respective records matches the IOA;
(b)
 
each
 
of
 
them
 
will
 
promptly
 
update
 
their
 
records
 
to
 
reflect
 
the
 
discharge
 
of
 
the
 
Issuer's
obligations with
 
respect to
 
the
 
Securities upon
 
the
 
receipt of
 
(i)
 
a
 
redemption payment
 
as
required pursuant
 
to
 
the terms
 
of the
 
Securities; and
 
(ii) a
 
confirmation from
 
the
 
Issuer or
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its agent of a mark-up (that is,
0010155-0003327 UKO2:
 
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increase) or
 
mark-down (that
 
is,
 
decrease) of
 
the IOA
 
of the
 
Securities; in
 
doing so,
 
each
ICSD will consult with the
 
other to ensure that the aggregate
 
of the amounts so updated by
them is equal to the total mark-up or mark-down notified to them;
(c)
 
each
 
of
 
them
 
will,
 
or
 
will
 
require
 
any
 
agent
 
appointed
 
by
 
it
 
to,
 
provide
 
the
 
necessary
information to
 
the Issuer's
 
agents to
 
enable the
 
Issuer's agents
 
to comply
 
with 2(c)
 
below;
and
(d)
 
each of them
 
confirms that, upon
 
the Issuer’s request, it
 
will produce for
 
the Issuer’s use
 
a
statement
 
showing
 
the
 
sum
 
of
 
the
 
total
 
nominal
 
amount
 
of
 
its
 
customer
 
holdings
 
for
 
the
Securities as of a specified date.
2.
 
The Issuer must procure that, in
 
relation to any Securities:
(a)
 
it
 
or
 
its
 
agents
 
will
 
inform
 
the
 
ICSDs
 
(through
 
the
 
common
 
service
 
provider
 
appointed
 
by
the
 
ICSDs
 
to
 
service the
 
Securities (the
CSP
)) of
 
the
 
initial
 
IOA
 
for
 
such
 
Securities
 
on
 
or
prior to the applicable closing date;
(b)
 
if any event occurs that requires a mark-up or mark-down of the records that an ICSD holds
for its customers to reflect such
 
customers’ interest in such Securities, one of its
 
agents will
promptly
 
provide
 
details
 
of
 
the
 
amount
 
of
 
such
 
mark-up
 
or
 
mark-down,
 
together
 
with
 
a
description of the
 
event that
 
requires it, to
 
the ICSDs
 
(through the CSP)
 
to ensure that
 
the
IOA
 
of
 
such
 
NGN
 
Securities
 
in
 
the
 
records
 
of
 
the
 
ICSDs,
 
or
 
the
 
records
 
of
 
the
 
ICSDs
reflecting the IOA of such NSS Securities, remain(s) at all times accurate;
(c)
 
it or its agents will at least monthly perform a reconciliation process with
 
the ICSDs (through
the
 
CSP)
 
with
 
respect
 
to
 
the
 
IOA
 
for
 
such
 
Securities
 
and
 
will
 
promptly
 
inform
 
the
 
ICSDs
(through the CSP) of any discrepancies;
(d)
 
it
 
or
 
its
 
agents
 
will
 
promptly
 
assist
 
the
 
ICSDs
 
(through
 
the
 
CSP)
 
in
 
resolving
 
any
discrepancy identified in the IOA of such NGN Securities or in the records
 
reflecting the IOA
of such NSS Securities;
(e)
 
it or
 
its agents
 
will promptly
 
provide to
 
the ICSDs
 
(through the
 
CSP) details of
 
all amounts
paid under the
 
Securities (or,
 
where the Securities provide
 
for delivery of assets
 
other than
cash, of the assets so delivered);
(f)
 
it
 
or
 
its
 
agents
 
will
 
promptly
 
provide
 
to
 
the
 
ICSDs
 
(through
 
the
 
CSP)
 
any
 
changes
 
to
 
the
Securities
 
that
 
will
 
affect
 
the
 
amount
 
of,
 
or
 
date
 
for,
 
any
 
payment
 
due
 
under
 
such
Securities;
(g)
 
it
 
or
 
its
 
agents
 
will
 
promptly
 
provide
 
to
 
the
 
ICSDs
 
(through
 
the
 
CSP)
 
copies
 
of
 
all
information that is given to the holders of the Securities;
(h)
 
its
 
agents
 
will
 
promptly
 
pass
 
on
 
to
 
it
 
all
 
communications
 
they
 
receive
 
from
 
the
 
ICSDs
directly or through the CSP relating to the Securities; and
(i)
 
its
 
agents will
 
promptly notify
 
the ICSDs
 
(through the
 
CSP) of
 
any failure
 
by the
 
Issuer to
make any payment or delivery due under the Securities when due.
The
 
Issuer’s
 
obligations
 
under
 
this
 
Agreement
 
will
 
be
 
discharged
 
if
 
it
 
includes
 
provisions
substantially to
 
the effect
 
set out
 
in the
 
paragraph above
 
in any
 
agreement it
 
has with
 
its agents.
The
 
Issuer
 
agrees
 
that
 
the
 
ICSDs
 
may
 
rely
 
on
 
communication
 
from
 
its
 
agents
 
as
 
if
 
such
communication was received directly from the Issuer.
3.
 
This
 
Agreement
 
is
 
not
 
intended to
 
create
 
and
 
does
 
not
 
create
 
any
 
relationship of
 
agency
0010155-0003327 UKO2:
 
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between the parties to it.
 
exhibit25p150i0 exhibit25p150i0
0010155-0003327 UKO2:
 
2004375908.9
149
4.
 
This Agreement is governed by
 
the law of the
 
jurisdiction marked on Schedule
 
1.
Signed on behalf of:
Equinor ASA
By:
 
(
Signature of Authorised
 
Officer of Issuer or agent
 
with Authorisation of Issuer
)
Name of Signatory:
On behalf of Euroclear Bank
 
SA/NV
Stéphane
 
Bernard, Managing
 
Director,
 
Head
 
of
Asset
 
Servicing
 
&
 
Transaction
 
Operations
 
&
Client Services
On behalf of Clearstream
 
Banking, société
anonyme
Berthold Kracke
Member of Executive
 
Board
Laurence
 
Van
 
Der
 
Haegen,
 
Head
 
of
Department New Issues
Marc Kieffer, Executive Vice President,
Issuance & Distribution Services
exhibit25p151i0
0010155-0003327 UKO2:
 
2004375908.9
150
Schedule 1
Please tick one jurisdiction
 
only.
Austria
 
Latvia
Belgium
 
Liechtenstein
Canada
 
Lithuania
Cyprus
 
Luxembourg
Czech Republic
 
Malta
Denmark
 
Netherlands
England & Wales
Norway
Estonia
 
Poland
Finland
 
Portugal
France
 
Scotland
Germany
 
Slovakia
Greece
 
Slovenia
Hungary
 
Spain
Iceland
 
Switzerland
Ireland
 
Sweden
Italy
 
U.S.A. - New York
Japan
 
- Other State
(
Name of Other State
)
0010155-0003327 UKO2:
 
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151
SCHEDULE 8
ADDITIONAL DUTIES
 
OF THE AGENT
In relation to each Series
 
of Notes that are NGNs,
 
the Agent will comply
 
with the following provisions:
1.
 
The
 
Agent
 
will
 
inform
 
each
 
of
 
Euroclear
 
and
 
Clearstream,
 
Luxembourg
 
(the
ICSDs
),
through
 
the
 
common
 
service
 
provider
 
appointed
 
by
 
the
 
ICSDs
 
to
 
service
 
the
 
Notes
 
(the
CSP
),
 
of
 
the
 
initial
 
issue
 
outstanding
 
amount
 
(
IOA
)
 
for
 
each
 
Tranche
 
on
 
or
 
prior
 
to
 
the
relevant Issue Date.
2.
 
If
 
any
 
event
 
occurs
 
that
 
requires
 
a
 
mark
 
up
 
or
 
mark
 
down
 
of
 
the
 
records
 
which
 
an
 
ICSD
holds for its customers to reflect such customers' interest in the Notes, the Agent will (to the
extent known
 
to it)
 
promptly provide
 
details of
 
the amount
 
of such
 
mark up
 
or mark
 
down,
together with
 
a description
 
of the
 
event that
 
requires it,
 
to the
 
ICSDs (through
 
the
CSP)
to
ensure that the IOA of the Notes
 
remains at all times accurate.
3.
 
The Agent
 
will at
 
least once
 
every month
 
reconcile its
 
record of
 
the IOA
 
of the
 
Notes with
information received from the
 
ICSDs (through the CSP)
 
with respect to the
 
IOA maintained
by
 
the
 
ICSDs for
 
the
 
Notes and
 
will promptly
 
inform the
 
ICSDs
 
(through the
 
CSP)
 
of
 
any
discrepancies.
4.
 
The
 
Agent will
 
promptly assist
 
the
 
ICSDs (through
 
the
 
CSP) in
 
resolving any
 
discrepancy
identified in the IOA of the Notes.
5.
 
The Agent will promptly provide to
 
the ICSDs (through the CSP) details
 
of all amounts paid
by it under the Notes (or,
 
where the Notes provide for delivery of
 
assets other than cash, of
the assets so delivered).
6.
 
The Agent will
 
(to the
 
extent known to
 
it) promptly provide
 
to the ICSDs
 
(through the CSP)
notice
 
of any changes
 
to the
 
Notes that will
 
affect the
 
amount of, or
 
date for,
 
any payment
due under the Notes.
7.
 
The Agent will
 
(to the
 
extent known to
 
it) promptly provide to
 
the ICSDs (through
 
the CSP)
copies of all information that is given to the holders of the Notes.
8.
 
The
 
Agent
 
will
 
promptly
 
pass
 
on
 
to
 
the
 
Issuer
 
all
 
communications
 
it
 
receives
 
from
 
the
ICSDs
 
directly or through the CSP relating to the Notes.
9.
 
The
 
Agent
 
will (to
 
the
 
extent
 
known to
 
it)
 
promptly notify
 
the
 
ICSDs
 
(through the
 
CSP)
 
of
any failure by the Issuer to make any payment or delivery due under
 
the Notes when due.
[
Signature page to
 
Amended and Restated
 
Agency Agreement
]
SIGNATORIES
The Issuer
EQUINOR ASA
Forusbeen 50
N-4035 Stavanger
Norway
Telefax
 
No:
 
+ 47 51 99 90 17
Attention:
 
Compliance Officer, Group
Finance By:
The Guarantor
EQUINOR ENERGY
 
AS
Forusbeen 50
N-4035 Stavanger
Norway
Telefax
 
No:
 
+ 47 51 99 90 17
Attention:
 
Compliance Officer, Group
Finance By:
 
 
0010155-0003327 UKO2:
 
2004375908.9
123
The Agent
THE BANK OF NEW
 
YORK MELLON, LONDON
 
BRANCH
One Canada
 
Square
London E14 5AL
United Kingdom
Email:
 
corpsov4@bnymellon.co
m Copy to Fax:
 
+44 207 964 2536
Attention:
 
Corporate Trust Administration
 
EQUINOR ASA
By:
The other Paying Agent
THE BANK OF NEW
 
YORK MELLON SA/NV, LUXEMBOURG BRANCH
Vertigo Building
Polaris 2-4 rue
 
Eugene
Ruppert L-2453
Luxembourg
Telephone:
Luc Biever: +352 24 52 5320
Sebastien Loiseau: +352 24 52
 
4436
Rima Hachoud: +352
 
24 52
5673 Email:
LUXMB_SPS@bnymellon.co
m
Fax:
 
+352 24 52 42 04
Attention:
 
Corporate Trust Administration
 
EQUINOR ASA
All communications c/o
 
the Agent
By:
0010155-0003327 UKO2:
 
2004375908.9
124
APPENDIX 1
FORM OF CALCULATION AGENCY AGREEMENT
CALCULATION AGENCY AGREEMENT
[
 
]
EQUINOR ASA
as
Issuer
and
[EQUINOR ENERGY
 
AS
as Guarantor]
€20,000,000,000
EURO MEDIUM TERM
 
NOTE PROGRAMME
125
CONTENTS
Clause
 
Page
1.
2.
3.
4.
5.
6.
7.
8.
9.
10.
0010155-0003327 UKO2:
 
2004375908.9
126
CALCULATION AGENCY AGREEMENT
in respect of the
EQUINOR ASA
 
€20,000,000,000
EURO MEDIUM TERM
 
NOTE PROGRAMME
THIS AGREEMENT
is made on [
 
]
BETWEEN
:
(1)
EQUINOR ASA
of Forusbeen 50, N-4035 Stavanger, Norway
 
(the
Issuer
);
(2)
 
[
EQUINOR ENERGY AS
of Forusbeen 50, N-4035
 
Stavanger, Norway (the
Guarantor
)]; and
(3)
 
[
 
]
 
of
 
[
 
]
 
(the
Calculation
 
Agent
,
 
which
 
expression
 
shall
 
include
 
its
 
successor
or successors for the time being as calculation agent hereunder).
WHEREAS
:
(A)
 
The
 
Issuer
 
has
 
entered
 
into
 
an
 
amended
 
and
 
restated
 
Programme
 
Agreement
 
with
 
the
Dealers named
 
therein dated
 
9 May
 
2022 under which
 
the Issuer
 
may issue Euro
 
Medium
Term
 
Notes
 
(
Notes
)
 
with
 
an
 
aggregate
 
nominal
 
amount
 
of
 
up
 
to
 
€20,000,000,000
 
(or
 
its
equivalent in other currencies).
(B)
 
The
 
Notes
 
will
 
be
 
issued
 
subject
 
to
 
and
 
with
 
the
 
benefit
 
of
 
an
 
amended
 
and
 
restated
Agency Agreement (the
Agency Agreement
) dated 9 May
 
2022 and entered into
 
between
the
 
Issuer,
 
The
 
Bank
 
of
 
New
 
York
 
Mellon,
 
London
 
Branch
 
as
 
Agent
 
(the
Agent
which
expression
 
shall include
 
its
 
successor or
 
successors for
 
the
 
time
 
being under
 
the
 
Agency
Agreement) and the other parties named therein.
NOW IT IS HEREBY
 
AGREED
that:
1.
 
APPOINTMENT OF
 
THE CALCULATION AGENT
The Issuer hereby appoints [
 
]
 
as
 
Calculation
 
Agent
 
in
 
respect
 
of
 
each
 
Series
 
of
Notes described
 
in the
 
Schedule hereto
 
(the
Relevant
 
Notes
)
 
for the
 
purposes set
 
out
 
in
clause
 
below,
 
all
 
upon
 
the
 
provisions hereinafter
 
set
 
out.
 
The
 
agreement
 
of
 
the
 
parties
hereto that this Agreement
 
is to apply to
 
each Series of Relevant Notes
 
shall be evidenced
by the manuscript annotation and
 
signature in counterpart of the Schedule hereto.
2.
 
DUTIES OF CALCULATION AGENT
The
 
Calculation
 
Agent
 
shall
 
in
 
relation
 
to
 
each
 
Series
 
of
 
Relevant
 
Notes
 
perform
 
all
 
the
functions
 
and duties
 
imposed on
 
the Calculation
 
Agent by
 
the terms
 
and conditions
 
of the
Relevant Notes
 
(the
Conditions
) including
 
endorsing the
 
Schedule hereto
 
appropriately in
relation to
 
each Series
 
of Relevant
 
Notes.
 
In addition,
 
the Calculation
 
Agent agrees
 
that it
will
 
provide
 
a
 
copy
 
of
 
all
 
calculations
 
made
 
by
 
it
 
which
 
affect
 
the
 
nominal
 
amount
outstanding of
 
any Relevant Notes
 
which are
 
identified on the
 
Schedule as being
 
NGNs to
The
 
Bank
 
of
 
New
 
York
 
Mellon,
 
London
 
Branch
 
to
 
the
 
contact
 
details
 
set
 
out
 
on
 
the
signature page hereof.
Notwithstanding any
 
other provision
 
of this
 
Agreement, the
 
Calculation Agent
 
shall not
 
be
obliged
 
to perform
 
any functions
 
and duties
 
imposed on
 
it by
 
the Conditions
 
as a
 
result of
any
 
Benchmark
 
Amendments
 
and/or
 
Benchmark
 
Replacement
 
Conforming
 
Changes
 
(as
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applicable) enacted without
0010155-0003327 UKO2:
 
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the
 
consent
 
of
 
the
 
Calculation
 
Agent
 
if,
 
in
 
the
 
Calculation
 
Agent’s
 
opinion,
 
acting
reasonably
 
and
 
in
 
good
 
faith,
 
such
 
Benchmark
 
Amendments
 
and/or
 
Benchmark
Replacement Conforming
 
Changes (as
 
applicable) impose
 
more onerous
 
obligations upon
it
 
or
 
expose
 
it
 
to
 
additional
 
duties,
 
responsibilities
 
or
 
liability,
 
or
 
reduce
 
or
 
amend
 
the
protective provisions afforded to the Calculation Agent in the Conditions or
 
this Agreement.
3.
 
EXPENSES
[
To
be agreed at the time
 
of appointment
.]
4.
 
INDEMNITY
4.1
 
The Issuer shall indemnify
 
(and failing the Issuer
 
so indemnifying, the Guarantor
 
agrees so
to indemnify) the Calculation Agent against any loss, liability,
 
cost, claim, action, demand or
expense
 
(including,
 
but
 
not
 
limited
 
to,
 
all
 
reasonable
 
costs,
 
legal
 
fees,
 
charges
 
and
expenses paid or incurred in disputing or defending any of the foregoing) which it may incur
or which may be made
 
against the Calculation Agent as
 
a result of or
 
in connection with its
appointment
 
or
 
the
 
exercise
 
of
 
its
 
powers
 
and
 
duties
 
hereunder
 
except
 
such
 
as
 
may
 
(i)
result
 
from
 
its
 
own
 
default,
 
negligence
 
or
 
bad
 
faith
 
or
 
that
 
of
 
its
 
officers,
 
directors
 
or
employees
 
or
 
the
 
breach
 
by
 
it
 
of
 
the
 
terms
 
of
 
this
 
Agreement
 
or
 
(ii)
 
be
 
governed
 
by
 
any
other provision of this Agreement.
4.2
 
The
 
Calculation
 
Agent
 
shall
 
indemnify
 
the
 
Issuer
 
and
 
the
 
Guarantor
 
against
 
any
 
loss,
liability,
 
cost, claim, action, demand or
 
expense (including, but not limited
 
to, all reasonable
costs,
 
legal fees,
 
charges and
 
expenses paid
 
or incurred
 
in
 
disputing or
 
defending any
 
of
the
 
foregoing) which
 
the
 
Issuer may
 
incur or
 
which may
 
be made
 
against the
 
Issuer
 
as a
result of
 
the breach
 
by the
 
Calculation Agent of
 
the terms
 
of this
 
Agreement or its
 
default,
negligence or bad faith or that of its officers, directors or employees.
5.
 
CONDITIONS OF APPOINTMENT
5.1
 
In acting hereunder
 
and in connection
 
with the Relevant
 
Notes, the Calculation
 
Agent shall
act
 
solely
 
as
 
agent
 
of
 
the
 
Issuer
 
[and
 
the
 
Guarantor]
 
and
 
will
 
not
 
thereby
 
assume
 
any
obligations
 
towards
 
or
 
relationship
 
of
 
agency
 
or
 
trust
 
for
 
or
 
with
 
any
 
of
 
the
 
owners
 
or
holders of the Relevant Notes or the coupons (if any) appertaining
 
thereto (the
Coupons
).
5.2
 
In relation to
 
each issue of
 
Relevant Notes the
 
Calculation Agent hereby undertakes
 
to the
Issuer to
 
perform such
 
obligations and
 
duties, and
 
shall be
 
obliged to
 
perform such
 
duties
and
 
only
 
such
 
duties
 
as
 
are
 
herein
 
and
 
in
 
the
 
Conditions
 
specifically
 
set
 
forth
 
and
 
no
implied
 
duties
 
or
 
obligations
 
shall
 
be
 
read
 
into
 
this
 
Agreement
 
or
 
the
 
Relevant
 
Notes
against the
 
Calculation Agent,
 
other than
 
the duty
 
to act
 
honestly and
 
in good
 
faith and
 
to
exercise the diligence of a reasonably prudent agent in comparable
 
circumstances.
5.3
 
The
 
Calculation
 
Agent
 
may
 
consult
 
with
 
legal
 
and
 
other
 
professional
 
advisers
 
and
 
the
opinion of such advisers shall be full and complete protection
 
in respect of any action taken,
omitted
 
or
 
suffered
 
hereunder
 
in
 
good
 
faith
 
and
 
in
 
accordance
 
with
 
the
 
opinion
 
of
 
such
advisers.
5.4
 
The Calculation Agent
 
shall be
 
protected and
 
shall incur no
 
liability for
 
or in
 
respect of
 
any
action taken, omitted
 
or suffered in
 
reliance upon any
 
instruction, request or order
 
from the
Issuer
 
[or
 
the
 
Guarantor]
 
or
 
any
 
notice,
 
resolution,
 
direction,
 
consent,
 
certificate,
 
affidavit,
statement,
 
cable,
 
telex
 
or
 
other
 
paper
 
or
 
document
 
which
 
it
 
reasonably
 
believes
 
to
 
be
genuine and
 
to have
 
been delivered,
 
signed or
 
sent by
 
the proper
 
party or
 
parties or
 
upon
written instructions from the Issuer [or the Guarantor].
0010155-0003327 UKO2:
 
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5.5
 
The
 
Calculation
 
Agent
 
and
 
any
 
of
 
its
 
officers,
 
directors
 
and
 
employees
 
may
 
become
 
the
owner of, or acquire any interest in, any Notes or Coupons (if any) with the
 
same rights that
it
 
or
 
they
 
would
 
have
 
if
 
the
 
Calculation
 
Agent
 
were
 
not
 
appointed
 
hereunder,
 
and
 
may
engage
 
or
 
be
 
interested
 
in
 
any
 
financial
 
or
 
other
 
transaction
 
with
 
the
 
Issuer
 
[or
 
the
Guarantor] and may act on, or as depositary,
 
trustee or agent for, any committee or body of
holders
 
of
 
Notes
 
or
 
Coupons
 
(if
 
any)
 
or
 
in
 
connection
 
with
 
any
 
other
 
obligations
 
of
 
the
Issuer
 
[or
 
the
 
Guarantor]
 
as
 
freely
 
as
 
if
 
the
 
Calculation
 
Agent
 
were
 
not
 
appointed
hereunder.
6.
 
TERMINATION OF APPOINTMENT
6.1
 
The
 
Issuer
 
[or
 
the
 
Guarantor]
 
may
 
terminate
 
the
 
appointment
 
of
 
the
 
Calculation
 
Agent
 
at
any
 
time
 
by
 
giving
 
to
 
the
 
Calculation
 
Agent
 
at
 
least
 
45
 
days'
 
prior
 
written
 
notice
 
to
 
that
effect, provided that, so long as any of the Relevant Notes is outstanding:
(a)
 
such
 
notice
 
shall
 
not
 
expire
 
less
 
than
 
45
 
days
 
before
 
any
 
date
 
upon
 
which
 
any
payment is
 
due in respect of any Relevant Notes; and
(b)
 
notice
 
shall
 
be
 
given
 
in
 
accordance
 
with
 
the
 
Conditions,
 
to
 
the
 
holders
 
of
 
the
Relevant Notes at least 30 days prior to any removal of
 
the Calculation Agent.
6.2
 
Notwithstanding the provisions
 
of subclause
 
above, if at any
 
time:
(a)
 
the
 
Calculation
 
Agent
 
becomes
 
incapable
 
of
 
acting,
 
or
 
is
 
adjudged
 
bankrupt
 
or
insolvent, or files
 
a voluntary
 
petition in bankruptcy
 
or makes an
 
assignment for the
benefit of its
 
creditors or consents to
 
the appointment of
 
an administrator,
 
liquidator
or
 
administrative
 
or
 
other
 
receiver
 
of
 
all
 
or
 
any
 
substantial
 
part
 
of
 
its
 
property,
 
or
admits
 
in
 
writing
 
its
 
inability
 
to
 
pay
 
or
 
meet
 
its
 
debts
 
as
 
they
 
may
 
mature
 
or
suspends
 
payment
 
thereof,
 
or
 
if
 
any
 
order
 
of
 
any
 
court
 
is
 
entered
 
approving
 
any
petition
 
filed
 
by
 
or
 
against
 
it
 
under
 
the
 
provisions
 
of
 
any
 
applicable
 
bankruptcy
 
or
insolvency
 
law
 
or
 
if
 
a
 
receiver
 
of
 
it
 
or
 
of
 
all
 
or
 
a
 
substantial
 
part
 
of
 
its
 
property
 
is
appointed or
 
if any
 
officer takes
 
charge or
 
control of
 
the Calculation
 
Agent or
 
of its
property or affairs for the purpose of rehabilitation, conservation or liquidation; or
(b)
 
the Calculation
 
Agent fails
 
duly to
 
perform any
 
function or
 
duty imposed
 
upon it
 
by
the Conditions and this Agreement,
the
 
Issuer
 
[and
 
the
 
Guarantor]
 
may
 
forthwith
 
without
 
notice
 
terminate
 
the
 
appointment
 
of
the
 
Calculation
 
Agent,
 
in
 
which
 
event
 
notice
 
thereof
 
shall
 
be
 
given
 
to
 
the
 
holders
 
of
 
the
Relevant Notes, in accordance with the Conditions as soon as practicable
 
thereafter.
6.3
 
The
 
termination
 
of
 
the
 
appointment
 
pursuant
 
to
 
subclause
 
or
 
above
 
of
 
the
Calculation Agent hereunder shall not entitle the Calculation Agent to any
 
amount by way of
compensation but shall be without prejudice to any amount then
 
accrued due.
6.4
 
The
 
Calculation Agent
 
may
 
resign
 
its
 
appointment hereunder
 
at
 
any time
 
by
 
giving to
 
the
Issuer
 
[and
 
the
 
Guarantor]
 
at
 
least
 
90
 
days'
 
prior
 
written
 
notice
 
to
 
that
 
effect.
 
Following
receipt of
 
a notice
 
of resignation from
 
the Calculation
 
Agent, the
 
Issuer shall promptly
 
give
notice thereof to the holders
 
of the Relevant Notes, in accordance with the Conditions.
6.5
 
Notwithstanding the provisions of
 
subclauses
 
and
 
above, so long as
 
any of the
Relevant Notes
 
is outstanding, the
 
termination of the
 
appointment of the
 
Calculation Agent
(whether by
 
the Issuer
 
[and the
 
Guarantor] or
 
by the
 
resignation of
 
the Calculation
 
Agent)
shall not
 
be effective
 
unless upon the
 
expiry of the
 
relevant notice a
 
successor Calculation
Agent
 
has
 
been
 
appointed.
 
The
 
Issuer
 
[and
 
the
 
Guarantor]
 
agrees
 
with
 
the
 
Calculation
Agent
 
that
 
if,
 
by the
 
day falling
 
10
 
days
 
before
 
the
 
expiry
 
of
 
any
 
notice
 
under
 
subclause
0010155-0003327 UKO2:
 
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130
 
or
 
the
 
Issuer [and
 
the Guarantor]
 
has
 
not
0010155-0003327 UKO2:
 
2004375908.9
131
appointed
 
a
 
replacement
 
Calculation
 
Agent,
 
the
 
Calculation
 
Agent
 
shall
 
be
 
entitled,
 
on
behalf
 
of
 
the
 
Issuer
 
to
 
appoint
 
as
 
a
 
successor
 
Calculation
 
Agent
 
in
 
its
 
place
 
a
 
reputable
financial
 
institution
 
of
 
good
 
standing
 
which
 
the
 
Issuer
 
[and
 
the
 
Guarantor]
 
shall
 
approve
(such approval not to be unreasonably withheld or delayed).
6.6
 
Upon
 
its
 
appointment
 
becoming
 
effective,
 
a
 
successor
 
Calculation
 
Agent
 
shall
 
without
further
 
act,
 
deed
 
or
 
conveyance,
 
become
 
vested
 
with
 
all
 
the
 
authority,
 
rights,
 
powers,
trusts, immunities, duties and obligations of
 
such predecessor with like effect
 
as if originally
named as the Calculation Agent hereunder.
6.7
 
If the
 
appointment of the
 
Calculation Agent hereunder
 
is terminated (whether
 
by the Issuer
[and
 
the Guarantor]
 
or
 
by the
 
resignation of
 
the Calculation
 
Agent), the
 
Calculation Agent
shall,
 
on
 
the
 
date
 
on
 
which
 
such
 
termination
 
becomes
 
effective,
 
deliver
 
to
 
the
 
successor
Calculation Agent any records concerning the Relevant Notes
 
maintained by it (except such
documents and records
 
as it
 
is obliged by
 
law or
 
regulation to retain
 
or not to
 
release), but
shall have no other duties or responsibilities hereunder.
6.8
 
Any
 
corporation
 
into
 
which
 
the
 
Calculation
 
Agent
 
may
 
be
 
merged
 
or
 
converted,
 
or
 
any
corporation
 
with
 
which
 
the
 
Calculation
 
Agent
 
may
 
be
 
consolidated,
 
or
 
any
 
corporation
resulting from any merger,
 
conversion or consolidation to which
 
the Calculation Agent shall
be a party,
 
or any corporation to which the Calculation Agent shall sell or otherwise transfer
all
 
or
 
substantially all
 
of
 
its
 
assets
 
shall,
 
on
 
the
 
date
 
when
 
such
 
merger,
 
consolidation
 
or
transfer becomes effective
 
and to the
 
extent permitted by
 
any applicable laws,
 
become the
successor
 
Calculation
 
Agent
 
under
 
this
 
Agreement
 
without
 
the
 
execution
 
or
 
filing
 
of
 
any
paper or
 
any further
 
act on
 
the part
 
of any
 
of the
 
parties hereto,
 
unless otherwise required
by
 
the
 
Issuer
 
and
 
after
 
the
 
said
 
effective
 
date
 
all
 
references
 
in
 
this
 
Agreement
 
to
 
the
Calculation Agent
 
shall be
 
deemed to
 
be references
 
to such
 
corporation. Written
 
notice of
any such merger, conversion,
 
consolidation or transfer shall forthwith be given to the Issuer
and the Agent.
6.9
 
Upon giving notice of
 
the intended termination of the
 
appointment of the Calculation Agent,
the
 
Issuer
 
shall
 
use
 
all
 
reasonable
 
endeavours
 
to
 
appoint
 
a
 
further
 
financial
 
institution
 
of
good standing as successor Calculation Agent.
7.
 
NOTICES
Any notice or communication
 
given hereunder shall be
 
sufficiently given or served:
(a)
 
if
 
delivered
 
in
 
person
 
to
 
the
 
relevant
 
address
 
specified
 
on
 
the
 
signature
 
pages
hereof or such other
 
address as may be notified
 
by the recipient in
 
accordance with
this clause
 
and, if
 
so delivered,
 
shall be
 
deemed to
 
have been
 
delivered at
 
time of
receipt; or
(b)
 
if
 
by
 
email,
 
when
 
sent,
 
subject
 
to
 
no
 
delivery
 
failure
 
notification
 
being
 
received
 
by
the
 
sender
 
within
 
24
 
hours
 
of
 
the
 
time
 
of
 
sending,
 
to
 
the
 
relevant
 
email
 
address
specified
 
on
 
the
 
signature
 
pages
 
hereof
 
or
 
such
 
other
 
email
 
address
 
as
 
may
 
be
notified by the recipient in accordance with this clause; or
(c)
 
if sent
 
by facsimile
 
to the
 
relevant number
 
specified on
 
the signature
 
pages hereof
or
 
such
 
other
 
address
 
as
 
may
 
be
 
notified
 
by
 
the
 
recipient
 
in
 
accordance
 
with
 
this
clause
 
and,
 
if
 
so
 
sent,
 
shall
 
be
 
deemed
 
to
 
have
 
been
 
delivered
 
immediately
 
after
transmission provided such transmission is confirmed when an acknowledgement of
receipt is received.
Where a communication is received
 
after business hours it
 
shall be deemed to be
 
received
and become effective on the
 
next business day.
 
Every communication shall be irrevocable
0010155-0003327 UKO2:
 
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132
save in respect of any manifest error therein.
0010155-0003327 UKO2:
 
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8.
 
GENERAL
8.1
 
The descriptive headings in this Agreement are for
 
convenience of reference only and shall
not define or limit the provisions hereof.
8.2
 
This Agreement may
 
be executed by
 
any one
 
or more
 
of the
 
parties hereto in
 
any number
of counterparts,
 
each of which
 
shall be
 
deemed to be
 
an original, but
 
all such counterparts
shall together constitute one and the same instrument.
8.3
 
If
 
any
 
provision
 
in
 
or
 
obligation
 
under
 
this
 
Agreement
 
is
 
or
 
becomes
 
invalid,
 
illegal
 
or
unenforceable in
 
any respect
 
under the
 
law of
 
any jurisdiction,
 
that will
 
not affect
 
or impair
(i)
 
the
 
validity,
 
legality
 
or
 
enforceability
 
under
 
the
 
law
 
of
 
that
 
jurisdiction
 
of
 
any
 
other
provision in or obligation under this Agreement, and (ii)
 
the validity,
 
legality or enforceability
under the
 
law of
 
any other
 
jurisdiction of
 
that or
 
any other
 
provision in
 
or obligation
 
under
this Agreement
[
Consider whether contractual recognition language (pursuant
 
to Article 55 of the EU Bank
Recovery and
 
Resolution Directive) is required to be included.
]
9.
 
CONTRACT (RIGHTS OF
 
THIRD PARTIES) ACT 1999
A person
 
who is
 
not a
 
party to
 
this Agreement
 
has no
 
right under
 
the Contracts
 
(Rights of
Third Parties)
 
Act 1999
 
to enforce
 
any term
 
of this
 
Agreement but
 
this does
 
not affect
 
any
right or remedy of a third party which exists or is available
 
apart from that Act.
10.
 
GOVERNING LAW AND SUBMISSION
 
TO JURISDICTION
10.1
 
This
 
Agreement and
 
any non-contractual
 
obligations arising
 
out of
 
or in
 
connection
 
with it
are governed by, and shall be construed in accordance with, English law.
10.2
 
The courts of
 
England are to have
 
jurisdiction to settle any
 
disputes which may arise
 
out of
or
 
in
 
connection
 
with
 
this
 
Agreement
 
(including
 
a
 
dispute
 
relating
 
to
 
any
 
non-contractual
obligations
 
arising
 
out
 
of
 
or
 
in
 
connection
 
with
 
this
 
Agreement)
 
and
 
accordingly any
 
legal
action
 
or
 
proceedings
 
arising
 
out
 
of
 
or
 
in
 
connection
 
with
 
this
 
Agreement
 
(
Proceedings
)
(including
 
any
 
Proceedings
 
relating
 
to
 
any
 
non-contractual
 
obligations
 
arising
 
out
 
of
 
or
 
in
connection
 
with
 
this
 
Agreement)
 
may
 
be
 
brought
 
in
 
such
 
courts.
 
The
 
Issuer
 
[and
 
the
Guarantor
 
each]
 
irrevocably
 
submits
 
to
 
the
 
jurisdiction
 
of
 
such
 
courts
 
and
 
waives
 
any
objection
 
to
 
Proceedings
 
in
 
any
 
such
 
courts
 
whether
 
on
 
the
 
ground
 
of
 
venue
 
or
 
on
 
the
ground that the Proceedings have
 
been brought in an inconvenient forum.
 
This submission
is
 
made
 
for
 
the
 
benefit
 
of
 
the
 
Calculation
 
Agent
 
and
 
shall
 
not
 
limit
 
its
 
right
 
to
 
take
Proceedings in any other court of competent jurisdiction nor
 
shall the taking of Proceedings
in
 
one
 
or
 
more
 
jurisdictions
 
preclude
 
the
 
taking
 
of
 
Proceedings
 
in
 
any
 
other
 
jurisdiction
(whether concurrently or not).
10.3
 
The
 
Issuer
 
[and
 
the
 
Guarantor
 
each]
 
irrevocably
 
appoints
 
Equinor
 
UK
 
Limited
 
(whose
offices
 
are
 
at
 
the
 
date
 
of
 
this
 
Agreement
 
at
 
One
 
Kingdom
 
Street,
 
Paddington
 
Central,
London
 
W2
 
6BD)
 
as
 
its
 
agent
 
for
 
service
 
of
 
process
 
in
 
respect
 
of
 
any
 
Proceedings
 
in
England.
 
If for
 
any reason such
 
agent shall cease
 
to be
 
such agent for
 
service of
 
process,
the
 
Issuer
 
shall
 
forthwith,
 
on
 
request
 
of
 
the
 
Calculation
 
Agent,
 
appoint
 
a
 
new
 
agent
 
for
service
 
of
 
process
 
in
 
England
 
and
 
deliver
 
to
 
the
 
Calculation
 
Agent
 
a
 
copy
 
of
 
the
 
new
agent's
 
acceptance
 
of
 
that
 
appointment
 
within
 
30
 
days.
 
Nothing
 
in
 
this
 
Agreement
 
shall
affect the right to serve process in any other manner permitted by law.
IN WITNESS
whereof this Agreement has
 
been entered into the day
 
and year first above
 
written.
0010155-0003327 UKO2:
 
2004375908.9
134
SCHEDULE TO THE
 
CALCULATION AGENCY AGREEMENT
Series number
 
Issue Date
 
Maturity
Date
Title
and
Nomina
l
Amount
NGN
[Yes/No
]
Annotation
by
Calculation
Agent/Issuer
0010155-0003327 UKO2:
 
2004375908.9
135
SIGNATORIES
EQUINOR ASA
Forusbeen 50
N-4035 Stavanger
Norway
Telefax
 
No:
 
+ 47 51 99 90 17
Attention:
 
Compliance Officer, Group
Finance By:
[
EQUINOR ENERGY
 
AS
Forusbeen 50
N-4035 Stavanger
Norway
Telefax
 
No:
 
+ 47 51 99 90 17
Attention:
 
Compliance Officer, Group
Finance By:
 
]
[Name of Calculation Agent]
[Address of
 
Calculation
Agent] Telefax
 
No:
 
[
 
]
Attention:
 
[
 
]
By:
 
.............................................................................
Contact Details
THE BANK OF NEW
 
YORK MELLON, LONDON
 
BRANCH
One Canada
 
Square
London E14 5AL
United Kingdom
Email:
 
corpsov4@bnymellon.com
 
Copy to Fax:
 
+44 207 964 2536
Attention:
 
Corporate Trust Administration
 
EQUINOR ASA
 
 
 
 
 
 
 
 
 
Significant subsidiaries
The following table shows significant subsidiaries and significant equity accounted companies within the
 
Equinor group as of
 
31 December 2022.
Significant subsidiaries and significant equity accounted companies
Name
in %
Country of
incorporation
Name
in %
Country of
incorporation
Danske Commodities A/S
100
Denmark
Equinor New Energy AS
100
Norway
Equinor Angola Block 15 AS
100
Norway
Equinor Nigeria Energy Company Ltd.
100
Nigeria
Equinor Angola Block 17 AS
100
Norway
Equinor Refining Norway AS
100
Norway
Equinor Angola Block 31 AS
100
Norway
Equinor UK Ltd. (Group)
100
United Kingdom
Equinor Apsheron AS
100
Norway
Equinor US Holding Inc. (Group)
100
USA
Equinor Argentina AS
100
Norway
Equinor Ventures AS
100
Norway
Equinor Brasil Energia Ltda.
100
Brazil
Equinor Wind Power AS
100
Norway
Equinor BTC (Group)
100
Norway
Equinor Wind US LLC
100
USA
Equinor Canada Ltd. (Group)
100
Canada
Statholding AS (Group)
100
Norway
Equinor Dezassete AS
100
Norway
Wento Group
100
Poland
Equinor Energy AS
100
Norway
AWE-Arkona-Windpark Entwicklungs-
GmbH
1
25
Germany
Equinor Energy do Brasil Ltda.
100
Brazil
Bandurria Sur Investment SA
1
50
Argentina
Equinor Energy International AS
100
Norway
Hywind (Scotland) Ltd.
1
75
United Kingdom
Equinor Holding Netherlands BV
100
Netherlands
SCIRA Offshore Energy Ltd.
1
40
United Kingdom
Equinor In Amenas AS
100
Norway
Triton Power Holdings Ltd.
1
50
United Kingdom
Equinor In Salah AS
100
Norway
Doggerbank Offshore Wind Farm Project
1 Holdco Ltd.
1
40
United Kingdom
Equinor Insurance AS
100
Norway
Doggerbank Offshore Wind Farm Project
2 Holdco Ltd.
1
40
United Kingdom
Equinor International Netherlands
BV
100
Netherlands
Doggerbank Offshore Wind Farm Project
3 Holdco Ltd.
1
40
United Kingdom
Equinor Natural Gas LLC
100
USA
1) Equity accounted entities.
For investments, voting rights correspond to ownership.
exhibit11p1i1 exhibit11p1i0
Code of
 
Conduct
Dear Colleague,
 
Our vision for Equinor is to be recognised as a company
 
that is shaping the future of energy.
 
Our innovative, open
and collaborative culture is central to realising this vision.
 
In Equinor, how we deliver
 
is as important as what we
deliver. I strongly believe that
 
an ethical business culture is the cornerstone of a sustainable
 
company.
 
This Code of Conduct is your guide to ethical business
 
practice. It reflects our values and our belief that
conducting business in an ethical and transparent manner is
 
not just the
right
way to work, but is the
only
way to
work. The Code of Conduct includes mandatory requirements
 
for everyone who works on behalf of Equinor.
 
My
expectation is that the Code of Conduct, together with
 
your good judgment, will lead you to the right decisions.
You should
 
seek guidance from your leader or other internal
 
resources referred to in the Code of Conduct if you
are uncertain on how to proceed.
Fundamental changes are happening in our industry which has
 
a key role in the energy transition towards a net
zero society. From
 
geopolitics and energy markets to our industry and our climate,
 
we face new realities. But our
commitment to high ethical standards in our business operations
 
stays firm. It is more important than ever to earn
the trust of our stakeholders – our people, our owners,
 
our business partners and our communities. The Code of
Conduct will assist us in earning and sustaining this trust
 
and in building a prosperous company for the future.
 
We must work together to create our future Equinor.
 
I want Equinor to continue to be a leader in ethical business
conduct. I expect that you carefully consider your business
 
decisions to ensure that they are in line with the Code
of Conduct. Only then will we maintain Equinor’s reputation and continue
 
to earn the trust that allows the company
to succeed with our vision – the Equinor Way.
 
Anders Opedal
President and CEO
Table
 
of contents
1 The Equinor Way
1.1 Equinor’s Commitment
1.2 Our Code of Conduct
1.3 Your Responsibilities
1.4 Responsibilities for Leaders
1.5 Asking Questions and Reporting Concerns
1.6 Ethics Helpline
1.7 Non-Retaliation Policy
1.8 Consequences of Breaches
1.9 Ethics and Compliance in Equinor
2 Respecting our People
2.1 Equality, Diversity and Inclusion
2.2 Harassment and Intimidation
2.3 Safety and Security
2.4 Privacy and Data Protection
2.5 Drugs and Alcohol
2.6 Purchase of Sexual Services
 
3 Conducting our Operations
 
3.1 Anti-Corruption
3.2 Conflict of Interest
3.3 Directorships and Ownership Interests
3.4 International Trade Restrictions
3.5 Anti-Money Laundering and Facilitation of Tax
 
Evasion
3.6 Financial and Business Records and Reporting
3.7 Property and Assets
3.8 IT Solutions and IT Equipment
3.9 Information Management and Confidentiality
3.10 Inside Information
 
exhibit11p3i0
4 Relating to our Business Partners
4.1 Suppliers and Business Partners
 
4.2 Intermediaries
 
4.3 Fair Competition
 
4.4 Gifts, Hospitality and Expenses
 
5 Communities and Environment
 
5.1 Local Stakeholder Engagement
5.2 Environment
 
5.3 Public Communication
 
5.4 Public Affairs
 
5.5 Public Officials
 
The Code of Conduct will be printed in updated versions when deemed necessary. However,
 
any changes will be updated in
the electronic version as and when required, and this will always represent the most recent edition.
English and Norwegian are the official versions.
 
1 The Equinor way
1.1 Equinor’s Commitment
Our ability to create value is dependent on applying high ethical
 
standards to create a trust-based relationship
with our people, our owners, our business partners and our communities.
 
In our business activities, we will comply with applicable laws,
 
act in an ethical, sustainable and socially
responsible manner and practice good corporate governance.
 
We will conduct our business consistently with
 
the
United Nations Guiding Principles on Business and Human
 
Rights and the ten Principles of the Global Compact,
in the manner as set out in our Human Rights Policy.
 
We support the Paris Climate Agreement and the
 
UN
Sustainable Development Goals. We will maintain
 
an open dialogue on ethical issues, internally and
 
externally.
 
1.2 Our Code of Conduct
The Code of Conduct (the Code) sets out our expectations,
 
commitments and requirements for ethical conduct.
The Code applies to Equinor’s board members, employees and hired personnel.
 
The Code reflects our values: Open, Collaborative, Courageous,
 
and Caring. The Code includes our most
important requirements, provides references to more detailed
 
requirements in our governing documents and
refers to other helpful resources. However,
 
the Code does not remove the need for
 
you to exercise good
judgment.
 
The Code has been approved by the Equinor’s Board of Directors
 
and provided for in
The Equinor Book.
Additional requirements and helpful tools
●
 
Corporate policy CP02- Human rights policy
1.3 Your Responsibilities
We set high ethical standards for everyone who acts
 
on Equinor’s behalf and in an Equinor capacity.
 
It is your
responsibility to comply with the Code, both in letter and
 
in spirit. You
 
are also responsible for complying with
other governing documents and applicable laws relevant
 
to your work.
 
What this means to you
 
●
 
Familiarise yourself with the Code as well as other governing
 
documents and applicable laws relevant to
your work.
●
 
Act comfortably within our ethical standards and within the law.
 
Operating in a grey zone increases the
risk of things going wrong. When in doubt, disclose the issue to
 
your leader and discuss it openly.
●
 
Spend sufficient time on difficult decisions
 
and raise issues early.
 
The wrong decisions are often taken
when things have not been thought through properly and you
 
are pressured into taking a rash decision.
 
●
 
If there is a difference between a legal requirement
 
and the Code, apply the most stringent standard.
●
 
Participate in required ethics and compliance training
 
and confirm annually that you have familiarised
yourself and will comply with the Code.
 
1.4 Responsibilities for Leaders
We are committed to recruiting and continuously
 
developing the best leaders for our company.
 
We expect our
leaders to demonstrate ownership and commitment to our ethical
 
standards by what they say and do. As a leader
you must ensure that activities within your area of responsibility
 
are carried out in accordance with the Code, other
governing documents and applicable laws.
What this means to you
 
●
Be a role model for ethical leadership through promotion
 
of our values and ethical standards. Show by
behaviour what it means to act with integrity.
●
Communicate the requirements in the Code and give advice
 
on its interpretation and application.
 
●
Facilitate a working environment free from harassment, bullying
 
and discrimination.
●
Create an environment where people feel comfortable speaking
 
up and asking questions without the risk
of retaliation.
 
●
Be consistent when enforcing our standards and holding people
 
accountable for their behaviour at work.
 
●
Make sure your team members participate in required
 
ethics and compliance training.
 
1.5 Asking Questions and Reporting Concerns
 
The Code aims at being as clear and direct as possible,
 
but it cannot address every situation that may arise. We
have an open communications policy,
 
and you should raise questions or seek advice when you
 
are uncertain
about how to proceed in any given situation.
 
If you suspect a possible violation of the Code or other
 
unethical conduct, it is your duty to report it immediately.
This includes any attempts of corruption you may become
 
aware of. We recognise that raising a concern
 
is not
always easy and we have several channels for taking concerns
 
forward.
 
What this means to you
 
●
 
Inform your leader immediately if you become aware of any activity
 
that you think is a violation of the
Code. Alternatively,
 
you can contact your leader’s superior.
 
●
 
If you do not feel comfortable with those options, you can
 
contact your local people and organisation
representative, your local compliance officer or
 
the legal, ethics and compliance function.
 
●
 
If you are uncomfortable using any of these channels, you
 
can report your concern to the Ethics Helpline.
 
●
 
You may use
 
the same channels to ask any questions regarding complian
 
ce with the Code.
1.6 The Ethics Helpline
 
The Ethics Helpline is a multi-language service available 24/7 providing phone service and a web portal. It is available to
anyone who has a legitimate concern. You may choose to remain anonymous, if permitted by law.
Additional requirements and helpful tools
●
 
WR1408 Ethics Helpline
1.7 Non-Retaliation Policy
 
We will not tolerate any form of retaliation against any person who has raised an ethical or legal concern in good faith. Acting
in good faith means that you have made a sincere report in a responsible manner through any of the channels listed above.
This applies even if your report does not turn out to be an actual violation.
1.8 Consequences of Breaches
We will not tolerate any breaches of the Code or
 
the law. Potential misconduct
 
may be investigated by corporate
audit or other relevant internal or external experts. We
 
will pursue remedial measures or other follow up of
personnel if you breach the Code or laws. The same applies
 
to leaders who disregard or tolerate such breaches
either through negligence or actual knowledge. The remedial
 
measures may include termination of your
employment contract and reporting to relevant authorities.
 
Incidents of ethical misconduct shall be registered and reported
 
in accordance with our governing documents.
exhibit11p6i0
Additional requirements and helpful tools
●
 
FR16 People and leadership
 
●
 
WR2417 Ethics incident reporting
1.9 Ethics and Compliance in Equinor
We work in a systematic manner to ensure compliance
 
with the Code and applicable laws. Our ethics and
compliance programmes apply to all parts of Equinor.
 
Our ethics and compliance function, headed by the Chief
Ethics and Compliance Officer,
 
is responsible for supervising Equinor’s ethics and compliance activities,
 
including
guidance on the Code and following up potential breaches.
 
The Chief Ethics and Compliance Officer will appoint
one compliance officer to assist in such work
 
for each business area and for selected corporate staff
 
functions.
The business areas and corporate functions shall appoint
 
local compliance officers where required.
 
The corporate executive committee constitutes Equinor’s ethics committee.
 
In addition, ethics committees have
been established in the business areas and most corporate functions,
 
comprising the respective management
teams. The committees will ensure a strong focus on,
 
common understanding of, and compliance with Equinor’s
ethical requirements.
Additional requirements and helpful tools
●
 
Corporate directive CD04-
 
Committees
●
 
WR2595 The compliance officer role
2 Respecting our people
2.1
Equality, Diversity and Inclusion
Every employee is an important member of the Equinor
 
team. We are committed to providing an inclusive
environment recognised for its equality and diversity,
 
and we will treat everyone with fairness, respect and
 
dignity.
We do not tolerate any discrimination of colleagues
 
or others affected by our operations. Discrimination
 
includes
exclusion, preference or illegal distinction based on ethnicity,
 
age, gender, gender identity,
 
disability, sexual
orientation, religion or belief, political views, or any other
 
characteristic that compromise the principle of equality.
 
What this means to you
 
●
 
Treat everyone with fairness, respect
 
and dignity.
●
 
Base your work-related decisions on merit and not on other characteristics
 
that result in compromising the
principle of equality.
 
Additional requirements and helpful tools
●
 
FR16 People and leadership
2.2 Harassment and Intimidation
Courtesy and respect are important aspects of a sound working
 
environment and business dealings. We
 
expect
you to treat everyone you meet through work or work-related
 
activities in a respectful manner.
 
We will not tolerate
any form of harassment or actions that reasonably can
 
be considered as offensive or intimidating,
 
including any
form of unwanted or troublesome attention of a sexual
 
nature.
 
What this means to you
 
●
 
Take
 
responsibility to create and maintain a good working environment.
●
 
Never engage in harassment, bullying, workplace violence
 
or other behaviour that colleagues or business
partners may regard as threatening or degrading.
 
●
 
Offensive messages, derogatory remarks and inappropriate
 
jokes are never acceptable.
 
●
 
Respect other people’s customs and culture.
 
●
 
Speak up if you observe or experience harassment or intimidating
 
behaviour
Additional requirements and helpful tools
●
 
GL0658 Handle harassment/bullying complaint
2.3 Safety and Security
Equinor’s safety and security vision is zero harm. We
 
are committed to providing a safe, healthy and secure
environment for all personnel at our facilities and job sites,
 
preventing accidents and incidents from affecting
people, environment and our assets. To
 
build a culture that is Always Safe will require consistent
 
use of I am
Safety expectations, Security Rules, Life Saving Rules
 
and a continued focus on building a proactive safety
culture applying Human and Organizational Performance Principles.
 
What this means to you
 
●
 
Safety and security is everyone’s responsibility.
 
You must
 
understand and act on your responsibilities to
contribute to a healthy,
 
safe and secure work environment.
 
●
 
Stop work immediately if you consider it unsafe.
 
●
 
Report any incident or unsafe condition as soon as possible.
 
If you see something, say something.
●
 
Know the relevant emergency procedures for your work.
Additional requirements and helpful tools
●
 
FR10 Safety and security
●
 
Corporate policy CP03 - Security policy
2.4 Privacy and Data Protection
Privacy and data protection laws protect the integrity and confidentiality
 
of a person’s private information. We
 
are
committed to protecting the privacy rights of our employees
 
and everyone with whom we do business. We will
only use personal data for appropriate purposes, and personal
 
data will be processed in accordance with
applicable laws, internal requirements and Equinor’s Binding Corporate
 
Rules.
What this means to you
 
●
 
Respect everyone’s right to privacy.
 
If your job includes handling personal data, make sure that
 
you are
sufficiently familiar with and comply with our internal
 
requirements for processing of personal data.
 
●
 
If you have permanent or regular access to personal data,
 
or if you are involved in collection, copying,
storing, analysing, disclosing or otherwise using personal data, take
 
appropriate training.
Additional requirements and helpful tools
●
 
WR1495 Processing of personal data
 
●
 
Binding Corporate Rules
 
●
 
GL0473 Guideline for Processing of Personal Data
 
2.5 Drugs and Alcohol
 
Equinor is a drug and alcohol-free workplace. We
 
will not tolerate anyone being under the influence of drugs
 
or
alcohol while at work for Equinor.
 
Limited amounts of alcohol may,
 
however, be consumed
 
when local custom and
occasion make it appropriate, and provided the consumption
 
is not combined with operating machinery,
 
driving or
any other incompatible activity.
 
Tests
 
for drugs and alcohol may be conducted whenever deemed
 
necessary and
in accordance with applicable laws.
What this means to you
 
●
 
Never work under the influence of drugs or alcohol.
●
 
Be conscious about work-related events where alcohol is
 
served and show moderation.
Additional requirements and helpful tools
●
 
FR16 People and leadership
 
2.6 Purchase of Sexual Services
Purchase of sexual services may be illegal, support human
 
trafficking and pose a security risk.
 
Human trafficking
is a violation of human rights. Regardless of local rules,
 
regulations and customs, Equinor prohibits the purchase
of sexual services when on assignments or business trips
 
for Equinor. This also
 
includes any contribution to the
purchase of such services.
 
What this means to you
 
●
 
Never purchase sexual services when you are on business
 
trips or other assignments, including long-term
assignments.
●
 
Never influence others to purchase sexual services and never
 
accept to receive sexual services others
have paid for.
exhibit11p9i0
3 Conducting our operations
3.1 Anti-Corruption
Corruption undermines legitimate business activities, distorts
 
competition, ruins reputations and exposes
companies and individuals to risk. We have zero
 
tolerance for corruption in any form, including bribery,
facilitation payments and trading in influence. We will
 
comply with all applicable anti-corruption laws and
regulations and take active steps to ensure that corruption
 
does not occur in relation to Equinor’s business
activities.
Transparency is vital in the combat of corruption.
 
We are committed to conducting our business
 
activities in an
open and transparent manner,
 
promoting transparency in our industry and supporting
 
efforts to combat
corruption worldwide.
What this means to you
 
●
 
Never engage in, authorise or tolerate corruption at any
 
time for any reason.
 
●
 
Never offer or accept an improper advantage. An
 
improper advantage is an advantage that has no
legitimate business purpose and is given to influence the
 
recipient’s decision making.
 
Security Classification: Open
 
- Status:
Final
●
 
Payment extorted from you under threat of life, health,
 
safety or illegal detention is allowed and will not
result in any form of retaliation, but you must report the
 
payment immediately.
●
 
Know your business partner,
 
follow our integrity due diligence requirements and never
 
engage others to
do something we cannot ethically or legally do ourselves.
●
 
Participate in required anti-corruption training and understand the
 
risks you face in your work.
 
Additional requirements and helpful tools
●
 
Anti-corruption compliance manual
 
●
 
Anti-Corruption Compliance Program
 
3.2 Conflict of Interest
Equinor respects your right to manage your personal affairs
 
and investments. However,
 
a conflict of interest may
occur when your personal interests and Equinor’s interests are different
 
and this may interfere with your ability to
make the right decision for Equinor.
 
We expect you to always act in the
 
best interest of Equinor when you are
representing the company.
 
You should
 
avoid situations with actual, potential or perceived conflict
 
of interest.
 
What this means to you
 
●
 
Do not work in connection with any Equinor or Equinor
 
related transaction, procurement, contract award
or other matter in which you have, or a related party has
 
a financial interest. A related party means your
partner, close relative or any
 
other person with whom you or they have close relations.
 
●
 
The same restriction applies where there are other circumstances
 
that undermine trust in your ability to
act in the best interest of Equinor.
●
 
Be open, disclose and discuss with your leader any actual,
 
potential or perceived conflict of interest. The
leader will then decide whether any measures should
 
be taken, for instance stepping back from the
situation that caused the conflict of interest.
 
3.3 Directorships and Ownership Interests
 
We expect you to spend your full working day on
 
Equinor matters. Before accepting external directorships
 
or other
material assignments, you must obtain prior written consent from
 
your senior vice president or,
 
for any employees
above this level, your leader.
 
If you hold directorships on behalf of Equinor,
 
you are not entitled to board
remuneration, but if you hold directorships in a private
 
capacity, you may retain
 
any remuneration paid. Elected
employee representatives on the board of Equinor ASA may
 
receive the remuneration decided by the corporate
assembly.
 
There are certain specific requirements for registering
 
directorships for the following group of employees: (1)
 
The
CEO, executive vice presidents and senior vice presidents; (2) employee
 
representatives on the board of Equinor
ASA and (3) employees exerting influence on Equinor’s procurement or
 
other contract awards. These categories
of employees must register all directorships, except directorships
 
in Equinor subsidiaries or when representing
Equinor in non-controlled companies, in our personnel data system.
 
This information must be updated on a
continuous basis and verified once a year.
Furthermore, employees in groups (1) and (2) cannot hold
 
ownership interests, or options to ownership interests,
directly or indirectly,
 
in any company that does or seeks to do business
 
with Equinor if the employee can exert
influence on business decisions related to such company.
 
The same applies to companies that are competitors
 
to
Equinor. This prohibition does
 
not apply to ownership interests in securities funds
 
or shares in Equinor ASA.
 
What this means to you
 
●
 
Ensure you have the required approval before accepting a
 
directorship or material assignment for another
company.
 
●
 
Note the special requirements for registration of directorships
 
for certain employees.
 
●
 
Note the special prohibition of ownership interests in other companies
 
for certain employees.
Additional requirements and helpful tools
●
 
GL0548 Equinor Board of directors handbook
 
 
Security Classification: Open
 
- Status:
Final
3.4 International Trade Restrictions
Countries can impose various economic sanctions restrictions
 
targeting business dealings with specific countries,
economic sectors, entities or individuals of concern. Export
 
controls on the export or in-country transfer of certain
restricted items, technology and software are also common.
 
We will comply with all applicable economic
sanctions as well as export and import control laws. We
 
will assess whether government authorisation is required
before engaging in activities involving restricted items, sanctioned
 
parties or countries and will obtain and comply
with all required authorisations.
 
What this means to you
 
●
 
Screen your business partners, suppliers and other parties
 
(including any ownership of the same) against
relevant restricted parties’ lists.
 
●
 
Obtain and comply with necessary governmental licences
 
where cross-border export or import activity
involves restricted items, technology or software.
 
●
 
Be mindful that both sanctions and export control regulations
 
are complex and subject to frequent
changes. Stay updated on the rules applicable to your
 
business activity.
●
 
Seek advice from the legal department if asked to deal with
 
a sanctioned party,
 
market or country.
 
Additional requirements and helpful tools
●
 
WR2988 Integrity due diligence
●
 
GL0358 Legal recommendations for compliance with EU/Norway sanctions related to certain countries
 
●
 
Sanctions search tool on the integrity due diligence portal
 
3.5 Anti-Money Laundering and Facilitation of Tax Evasion
Money laundering is illegal and supports other criminal activities,
 
including drug trafficking, terrorism, corruption,
human rights violations and tax evasion. Money laundering
 
is the processes of disguising the proceeds of crime
 
in
order to hide its illegal origins or otherwise dealing with the
 
proceeds of crime. Criminal proceeds include not only
money, but all forms
 
of assets, real estate and intangible property that
 
are derived from criminal activity.
 
We will
comply with all applicable anti-money laundering laws.
Tax
 
evasion is an illegal practice where a person or entity evades
 
paying their actual tax liability.
 
We do not
tolerate the facilitation of tax evasion by persons who
 
act for or on behalf of Equinor.
What this means to you
 
●
 
Be attentive to unusual payments, invoicing and banking arrangement
 
as well as unusual tax status of
suppliers.
●
 
Seek advice from the legal department if you need a better understanding
 
of money laundering or tax
evasion and how to mitigate such risk to Equinor.
●
 
Know your business partners and make sure you follow our integrity
 
due diligence requirements.
3.6 Financial and Business Records and Reporting
 
Recording and reporting financial or non-financial information
 
completely,
 
accurately and objectively are essential
for Equinor’s credibility and reputation. It is also a prerequisite
 
for meeting legal and regulatory obligations and
reporting standards. We are committed to transparency
 
and accuracy in all our dealings, and we will provide full,
fair, accurate and understandable
 
disclosures in our financial and non-financial reports,
 
in documents filed with
regulatory authorities and in other public communication.
 
What this means to you
 
●
 
The data and information you enter in our records must be
 
accurate, complete, and reliable. This includes
financial and non- financial information for both internal
 
and external use.
●
 
Any accounting information you provide must be complete,
 
accurate, valid, and recorded in accordance
with applicable laws, relevant accounting and reporting
 
standards and the Equinor accounting manual.
 
Security Classification: Open
 
- Status:
Final
●
 
Make sure you are familiar with and comply with internal control
 
over financial reporting requirements
relevant to your work.
●
 
Never enter false, misleading, or artificial entries in our
 
records and reports. Any such intentional act may
be treated as fraud.
●
 
The highest standard of care should always be exercised
 
when recording and reporting financial or non-
financial information.
●
 
If you suspect or become aware of any indications of fraud,
 
improper financial business records and
reporting or allegations of such, you must report it to your
 
leader or the Ethics Helpline immediately.
 
Additional requirements and helpful tools
●
 
FR14 Finance and control
●
 
WR1366 Accounting manual
 
3.7 Property and Assets
We trust you with Equinor’s assets so that you can effectively
 
do your work. You
 
are responsible for safeguarding
those assets against loss, theft and misuse. Equinor’s assets
 
include facilities, equipment, IT solutions and IT
equipment, information, intangible property rights and financial
 
assets. We will not tolerate any misuse of
 
our
assets for personal benefit.
What this means to you
 
●
 
Any use of Equinor’s assets for purposes not directly related to our
 
business, unless specifically provided
for in this Code, requires permission from your leader.
●
 
Ensure that documents used to obtain company funds
 
and property are accurate and complete. This
includes time sheets, invoices, benefit claims and travel and expense
 
reimbursement reports and
underlying documentation. Inaccurate or unsubstantiated records
 
may be treated as fraud.
●
 
As a leader you must ensure proper control before you
 
approve any time sheets, invoices, benefit claims
and travel and expense reimbursement reports and underlying
 
documentation for people in your team.
3.8 IT Solutions and IT Equipment
Our IT solutions and IT equipment shall be used for business
 
purposes. Information produced and stored on our
authorized IT solutions and IT equipment is Equinor’s property and
 
may be accessed in accordance with
applicable law. Cyberattacks
 
and malicious activitiesy are a continuous threat to Equinor,
 
and the use of our
authorized IT solutions and IT equipment is monitored
 
to detect such risk. This includes blocking access to
inappropriate web sites and interception of any information transmitted
 
by or stored on our IT solutions.
What this means to you
 
●
 
Handle and archive documents according to Equinor’s information management
 
requirements and
security classification system.
●
 
Never use our IT solutions or IT equipment to perform
 
illegal or unethical activities, including downloading,
streaming, or sharing of offensive material.
●
 
You must
 
be vigilant of cyberattacks and malicious activities, such as
 
phishing, and immediately report
any incidents.
●
 
Limited personal use of our IT solutions and IT equipment
 
is permitted, but such use should be kept to a
minimum and have no adverse effect on cost, IT security
 
or productivity. This
 
includes private use of
social media.
●
 
Respect computer software copyrights and comply with the terms
 
and conditions of software licenses.
 
Additional requirements and helpful tools
●
 
WR2893 IT Rules
 
 
Security Classification: Open
 
- Status:
Final
3.9 Information Management and Confidentiality
During the course of business, we gain and produce information
 
that is vital to our financial and business integrity.
Such information may,
 
however, also be valuable for competitors
 
and others. We will protect information created
by us, or given to us, to ensure appropriate confidentiality
 
and integrity. It
 
is important to share information across
the organisation to ensure collaboration, efficiency
 
and experience transfer,
 
but information transfer and access
must take place in accordance with our security classification system
 
for information management.
 
What this means to you
 
●
 
Make sure you are familiar with and comply with our information
 
management and security classification
system when handling company information.
●
 
Do not use Equinor’s information acquired through your work for personal
 
advantage or for the purpose of
competing with Equinor.
●
 
You have
 
a duty of confidentiality,
 
which applies even after your employment or assignment
 
with Equinor
has ended.
Additional requirements and helpful tools
●
 
WR0158 Manage data and information
 
3.10 Inside Information
Equinor supports fair and open securities markets wherever
 
we operate. You
 
may become aware of information
about Equinor or other companies that is not publicly available.
 
Such information may constitute inside
information. Inside information is precise information likely
 
to have a significant effect on the price of securities
and which is not publicly available or commonly known
 
to the market. If you are in possession of inside
information, even if acquired incidentally,
 
you have a legal duty of confidentiality and due care
 
of handling to
prevent such information from coming into the possession of
 
unauthorised persons. Any use of inside information
about Equinor or other publicly traded companies for personal
 
gain is prohibited.
Certain persons, such as members of the Board of Directors
 
and Corporate Executive Committee, are considered
primary insiders. Additional restrictions apply for primary
 
insiders.
What this means to you
 
●
 
Never buy or sell Equinor’s or other companies’ shares or other securities,
 
or provide advice to others’
investment decisions, when you have access to inside information
 
.
●
 
Holders of inside information must treat this confidentially
 
and can only pass such information to
individuals who need it in their work for Equinor based
 
on authorisation from the information owner.
●
 
Holders of inside information relevant for the Equinor share
 
price must be listed in Equinor’s insider listing
system.
 
●
 
The restriction on buying Equinor shares when you hold inside
 
information does not prevent you from
participating in our share savings program.
Additional requirements and helpful tools
●
 
WR1921 Primary insiders
●
 
WR2305 Handling of Inside Information related to commodities
●
 
WR2401 Inside information
 
 
exhibit11p14i0
Security Classification: Open
 
- Status:
Final
4 Relating to our business partners
4.1 Suppliers and Business Partners
Business relationships based on trust and transparency
 
are vital to our business. Our suppliers and business
partners are essential to our ability to do business but
 
can also cause or contribute to harm people and expose
 
us
to reputational, operational and legal risk. We expect
 
our suppliers and business partners to comply with
applicable laws, respect internationally recognised human rights
 
and adhere to ethical standards which are
consistent with our ethical requirements when working for or together
 
with us. We seek to work with others who
share our commitment to ethics and compliance, and
 
we manage risk through in-depth knowledge of our
suppliers, business partners and markets. Equinor will
 
not voluntarily enter into partnerships with anonymously
owned companies.
 
What this means to you
 
●
 
Before you establish or amend any business relationship,
 
you must follow our procedures for integrity due
diligence and human rights due diligence.
●
 
Communicate and follow-up regularly and clearly our
 
expectations to our suppliers and business partners.
●
 
Report any misconduct by a supplier or business partner to your
 
leader or any of the other reporting
channels listed in the Code.
 
Security Classification: Open
 
- Status:
Final
Additional requirements and helpful tools
●
 
Corporate policy CP02- Human rights policy
●
 
WR2988 Integrity due diligence
 
●
 
WR2452 Joint venture management related to anti-corruption compliance
●
 
GL0349 Guidance on anti-corruption for non Equinor operated joint ventures
●
 
GL0754 Guidance on partnerships with anonymously owned companies
●
 
Integrity due diligence portal
 
4.2 Intermediaries
Intermediaries are a particular type of business partner and include
 
agents, consultants, lobbyists and others who
act as a link between Equinor and others. The use of
 
intermediaries may pose a particular risk to us, and we
therefore have additional requirements for hiring intermediaries.
 
It is mandatory to perform integrity due diligence
on all intermediaries. The agreed compensation must be proportionate
 
to the service rendered and only paid
against satisfactory documentation of work performed, which
 
must be regularly monitored. The agreement with
the intermediary must be made in writing, describe the
 
true relationship with Equinor and include an obligation
 
to
follow the Code.
 
What this means to you
 
●
 
Any intermediary you plan to hire must be subject to
 
integrity due diligence.
●
 
Monitor regularly the work performed by the intermediary
 
to ensure it is in line with the Code.
4.3 Fair Competition
 
We believe in the benefits of competition, and Equinor
 
will always compete in a fair and ethically justifiable
manner. We will comply
 
with applicable competition and antitrust laws. We
 
will not engage in or tolerate anyone
who engages in anti-competitive behaviour,
 
such as price fixing, bid rigging, market sharing or abuse
 
of market
power.
We participate in legal collaborative projects with other
 
companies and share information required for such
projects. It may be a violation of competition and antitrust
 
rules to receive or share with competitors non-public
commercially sensitive information beyond what is necessary
 
for a legal cooperation. Commercially sensitive
information includes information which may reduce uncertainty
 
about future market conduct, such as prices,
competitive bids, commercial strategies, costs, customers
 
and suppliers.
 
What this means to you
 
●
 
Do not enter into anti-competitive agreements or engage in
 
anti-competitive conduct, such as agreeing
with competitors to fix prices or to allocate markets by territory,
 
by products or by customers.
●
 
Be vigilant of situations where non-public commercially
 
sensitive information may be exchanged and
speak out against disclosure of information by others to
 
you. Never share such information with
competitors.
●
 
Competition laws are complex and often require a detailed
 
assessment of facts. If you are in doubt, seek
advice from the legal department.
●
 
Participate in required competition and antitrust compliance
 
training.
Additional requirements and helpful tools
●
 
WR2447 Competition law compliance
●
 
WR1837 Inspections by authorities
●
 
Competition compliance manual
 
 
Security Classification: Open
 
- Status:
Final
4.4 Gifts, Hospitality and Expenses
 
Relationships with our business partners can be built and strengthened
 
through legitimate networking and social
interaction. However, giving or
 
accepting gifts and hospitality may be regarded as
 
corruption in certain situations,
and we have strict limits for when we allow the giving or
 
acceptance of gifts and hospitality.
As a general rule, we do not offer or accept
 
gifts, except for promotional items of minimal value. In a situation
where it would clearly give offence to refuse, the gift
 
may be accepted if it is of reasonable value and handed
 
over
to Equinor immediately.
 
We only offer or accept hospitality where
 
there is a clear business reason for Equinor to
participate and the costs involved are reasonable. We
 
will always pay our own costs related to travel,
accommodation and other related expenses. Except as
 
otherwise stated in the Code, we do not pay travel,
accommodation and other related expenses for others.
 
What this means to you
 
●
 
Never offer or accept gifts, except for promotional items
 
of minimal value.
●
 
Before accepting or offering hospitality,
 
ensure that it is in line with our requirements. Written
 
approval
from your leader is required unless the hospitality clearly
 
is acceptable.
●
 
Ask yourself how the acceptance or offer would be perceived
 
by others and never offer or accept anything
that is or could be perceived as an improper advantage.
●
 
Ensure that all acceptance and offering of hospitality
 
are open, transparent and properly documented.
Additional requirements and helpful tools
●
 
GL0537 Offering and accepting gifts, hospitality and expenses
 
●
 
GL0782 Compliance Guideline on Social Investments
●
 
WR1803 Management of social investment
 
 
exhibit11p17i0
Security Classification: Open
 
- Status:
Final
5 Communities and Environment
5.1 Local Stakeholder Engagement
Stakeholder engagement is a central element of our commitment
 
to create lasting local value.
 
Timely and meaningful engagement
 
with potentially affected stakeholders, including
 
through appropriate and
effective grievance mechanisms, is a central
 
element of our commitment to assess actual and potential
 
human
rights impacts linked to our activities or business relationships.
 
Where needed, we aim to take appropriate and
mitigating actions. Where we have caused or contributed to
 
adverse human rights impacts, we will provide or
cooperate in providing appropriate remediation.
In our engagement and dialogue with all stakeholders
 
we seek to understand their expectations and explore
opportunities for mutual benefits. Solutions identified must
 
be relevant to local conditions and our business
 
needs,
and comply with our values, policies and local regulations. Our
 
contribution to communities may include direct and
indirect employment, procurement of goods and services,
 
infrastructure development and competence building as
well as social investments.
What this means to you
 
 
Security Classification: Open
 
- Status:
Final
●
 
Familiarise yourself with our human rights policy and report any
 
potential or actual negative human rights
impact related to our operations or those of our business
 
partners.
●
 
Through human rights due diligence, systematically assess
 
and address the impact our activities may
have on stakeholders and take this into account when
 
making business decisions, including in relation to
their use of land, water and other natural resources.
●
 
When seeking to apply effective prevention and mitigation
 
actions, ensure that they are addressing
potential impacts fairly and without discriminating to any
 
affected members of the local community.
●
 
Be particularly attentive to those most vulnerable to adverse
 
impacts, including women, children and
indigenous peoples.
●
 
Actively identify opportunities related to our activities that can
 
contribute to local value creation through
local employment, procurement and capacity development.
●
 
Ensure that social contributions are made in compliance with our
 
anti-corruption requirements.
Additional requirements and helpful tools
●
 
Corporate policy CP02- Human rights policy
●
 
FR11 Sustainability
 
●
 
WR1803 Management of social investment
●
 
WR2297 The rights of indigenous and tribal people
●
 
WR2614 Community grievance mechanisms
●
 
GL0626 Community engagement guidelines
 
●
 
GL0782 Compliance Guideline on Social Investments
 
5.2 Environment
 
We systematically manage our environmental aspects
 
in accordance with good international practices and
principles and have to comply with applicable environmental
 
laws and regulations. Recognising that our activities
may have impacts on the environment, we apply a precautionary
 
approach and the principle of continual
improvement of our environmental performance, aiming to
 
protect nature and support nature conservation and
restoration initiatives. We work actively to limit greenhouse
 
gas emissions from our activities.
 
What this means to you
 
●
 
Ensure that the impacts our activities have or may have on
 
the environment are assessed and
communicated.
●
 
Ensure that relevant measures are taken into account when
 
making business decisions, including
application of the mitigation hierarchy (to avoid, minimise,
 
restore and offset potential significant direct
impacts in our projects), and the use of environmentally
 
friendly technologies.
●
 
Contribute actively to efficient use of resources, carbon
 
efficient operations and mitigation of negative
impacts and enhancement of positive impacts on the natural
 
environment.
●
 
Follow up and evaluate results and contribute to continual
 
improvement.
Additional requirements and helpful tools
●
 
Equinor Biodiversity position
 
5.3 Public Communication
 
 
Security Classification: Open
 
- Status:
Final
We believe that open, honest and accurate communication
 
is essential to our integrity and business success.
 
We
will communicate about Equinor in a consistent manner,
 
and only authorised persons may talk to the media,
members of the investment community or make statements on
 
Equinor’s behalf on social media. Any private use
of social media must not breach confidentiality obligations
 
and should not compromise Equinor’s reputation or
business interests.
 
What this means to you
 
●
 
Do not speak on Equinor’s behalf unless authorised to do so. Enquiries
 
from the media shall be directed
to corporate communication.
●
 
If you participate in social media, use good judgement and
 
show respect towards your colleagues,
business partners and communities. Be vigilant that participating
 
in social media may represent a security
risk.
Additional requirements and helpful tools
●
 
FR13 Communication
 
●
 
Social Media Guidelines
 
5.4 Public Affairs
 
We will make Equinor’s position known on important industry
 
matters through proactive engagement with
government policy makers and other stakeholders, such
 
as the media, civil society and international institutions.
However, we will not make
 
gifts, donations or otherwise support political parties or individual
 
politicians. We may
nevertheless be members of interest organisations relevant
 
for our industry that support political parties or certain
political issues. Any hiring of lobbyists will be in accordance with
 
applicable law and subject to full disclosure to
any external party they wish to influence that the lobbyist
 
represents Equinor.
 
What this means to you
 
●
 
Do not use company funds or resources to support any
 
political candidates or party.
 
Never use your
position in Equinor to try to influence any person to make
 
political contributions.
●
 
Ensure that all contracts with lobbyists impose an obligation
 
to disclose to any external party they wish to
influence that the lobbyist represents Equinor.
●
 
If you choose to participate in political activities or give
 
any public contributions, this must be personal and
not linked to Equinor.
 
5.5 Public Officials
 
In our business operations or public affairs activities,
 
we often interact with public officials. Many countries
 
have
rules regarding accepted conduct when dealing with public officials,
 
such as prohibiting giving anything of value.
We will never offer or authorise anything
 
of value or payments to public officials unless
 
specifically provided for in
the Code. We can, however,
 
cover the reasonable and legitimate travel, accommodation
 
and other related travel
expenses of public officials when they are related
 
to the promotion or demonstration of our products or services
 
or
the execution of a contract with a government.
 
What this means to you
 
●
 
Take
 
particular care when interacting with public officials
 
.
●
 
Never offer or agree to pay travel or accommodation
 
for any public official unless a hosting application
has been completed and properly approved by the Chief
 
Ethics and Compliance Officer and the relevant
EVP.
Additional requirements and helpful tools
●
 
Hosting form for public officials
 
 
Security Classification: Open
 
- Status:
Final
www.equinor.com
 
I, Anders Opedal, certify that:
 
1.
 
I have reviewed this Annual report on Form 20-F of Equinor ASA;
 
2.
 
Based on my knowledge, this report does not contain any untrue statement of a material
 
fact or omit to state a material fact
necessary to make the statements made, in light of the circumstances under which such
 
statements were made, not
misleading with respect to the period covered by this report;
 
3.
 
Based on my knowledge, the financial statements, and other financial information included
 
in this report, fairly present in all
material respects the financial condition, results of operations and cash flows of the company as
 
of, and for, the periods
presented in this report;
 
4.
 
The company’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and
procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control
 
over financial reporting (as
defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the company and have:
 
(a)
 
Designed such disclosure controls and procedures, or caused such disclosure controls and
 
procedures to be
designed under our supervision, to ensure that material information relating to the company, including its
consolidated subsidiaries, is made known to us by others within those entities, particularly during
 
the period in
which this report is being prepared;
 
(b)
 
Designed such internal control over financial reporting, or caused such internal control over financial
 
reporting to
be designed under our supervision, to provide reasonable assurance regarding the reliability
 
of financial reporting
and the preparation of financial statements for external purposes in accordance with generally
 
accepted
accounting principles;
 
(c)
 
Evaluated the effectiveness of the company’s disclosure controls and procedures and presented in this report our
conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered
by this report based on such evaluation; and
 
(d)
 
Disclosed in this report any change in the company’s internal control over financial reporting that occurred
 
during
the period covered by the annual report that has materially affected, or is reasonably likely to materially
 
affect, the
company’s internal control over financial reporting; and
 
5.
 
The company’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over
financial reporting, to the company’s auditors and the audit committee of the company’s board of directors (or persons
performing the equivalent functions):
 
(a)
 
All significant deficiencies and material weaknesses in the design or operation of internal control over financial
reporting which are reasonably likely to adversely affect the company’s ability to record, process, summarize and
report financial information; and
 
(b)
 
Any fraud, whether or not material, that involves management or other employees who
 
have a significant role in
the company’s internal control over financial reporting.
 
Date:
 
23 March 2023
 
By:
 
/s/
 
Anders Opedal
 
Name:
 
Anders Opedal
 
Title:
 
President and Chief Executive Officer
 
 
I, Torgrim Reitan,
 
certify that:
 
1.
 
I have reviewed this Annual report on Form 20-F of Equinor ASA;
 
2.
 
Based on my knowledge, this report does not contain any untrue statement of a material
 
fact or omit to state a material fact
necessary to make the statements made, in light of the circumstances under which such
 
statements were made, not
misleading with respect to the period covered by this report;
 
3.
 
Based on my knowledge, the financial statements, and other financial information included
 
in this report, fairly present in all
material respects the financial condition, results of operations and cash flows of the company as
 
of, and for, the periods
presented in this report;
 
4.
 
The company’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and
procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control
 
over financial reporting (as
defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the company and have:
 
(a)
 
Designed such disclosure controls and procedures, or caused such disclosure controls and
 
procedures to be
designed under our supervision, to ensure that material information relating to the company, including its
consolidated subsidiaries, is made known to us by others within those entities, particularly during
 
the period in
which this report is being prepared;
 
(b)
 
Designed such internal control over financial reporting, or caused such internal control over financial
 
reporting to
be designed under our supervision, to provide reasonable assurance regarding the reliability
 
of financial reporting
and the preparation of financial statements for external purposes in accordance with generally
 
accepted
accounting principles;
 
(c)
 
Evaluated the effectiveness of the company’s disclosure controls and procedures and presented in this report our
conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered
by this report based on such evaluation; and
 
(d)
 
Disclosed in this report any change in the company’s internal control over financial reporting that occurred
 
during
the period covered by the annual report that has materially affected, or is reasonably likely to materially
 
affect, the
company’s internal control over financial reporting; and
 
5.
 
The company’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over
financial reporting, to the company’s auditors and the audit committee of the company’s board of directors (or persons
performing the equivalent functions):
 
(a)
 
All significant deficiencies and material weaknesses in the design or operation of internal control over financial
reporting which are reasonably likely to adversely affect the company’s ability to record, process, summarize and
report financial information; and
 
(b)
 
Any fraud, whether or not material, that involves management or other employees who
 
have a significant role in
the company’s internal control over financial reporting.
 
Date:
 
23 March 2023
By:
 
/s/ _
Torgrim Reitan____________
 
___
Name:
 
Torgrim Reitan
Title:
 
Executive Vice President and Chief Financial Officer
 
 
Certification
 
Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
 
(Subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code)
 
Pursuant to section 906 of the Sarbanes-Oxley Act of 2002 (subsections (a) and (b)
 
of section 1350, chapter 63 of title 18, United
States Code), the undersigned officer of Equinor ASA, a company incorporated under the laws of Norway (the “Company”),
 
hereby
certifies, to such officer’s knowledge, that:
 
The Annual Report on Form 20-F for the year ended 31 December 2022 of the Company (the “Report”)
 
fully complies with the
requirements of section 13(a) or 15(d), as applicable, of the Securities Exchange Act of 1934
 
and information contained in the Report
fairly presents, in all material respects, the financial condition and results of operations of
 
the Company.
 
Date:
 
23 March 2023
By:
 
/s/
 
Anders Opedal
 
Name:
 
Anders Opedal
Title:
 
President and Chief Executive Officer
 
The foregoing certification is being furnished solely pursuant to section 906 of the Sarbanes-Oxley Act of
 
2002 (subsections (a) and
(b) of section 1350, chapter 63 of title 18, United States Code) and is not being
 
filed as part of the Report or as a separate disclosure
document.
 
A signed original of this written statement required by section 906 has been provided
 
to the Company and will be retained by the
Company and furnished to the Securities and Exchange Commission or its staff upon request.
 
 
Certification
 
Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
 
(Subsections (a) and (b) of Section 1350, Chapter 63 of Title 18, United States Code)
Pursuant to section 906 of the Sarbanes-Oxley Act of 2002 (subsections (a) and (b)
 
of section 1350, chapter 63 of title 18, United
States Code), the undersigned officer of Equinor ASA, a company incorporated under the laws of Norway (the “Company”),
 
hereby
certifies, to such officer’s knowledge, that:
 
The Annual Report on Form 20-F for the year ended 31 December 2022 of the Company (the “Report”)
 
fully complies with the
requirements of section 13(a) or 15(d), as applicable, of the Securities Exchange Act of 1934
 
and information contained in the Report
fairly presents, in all material respects, the financial condition and results of operations of
 
the Company.
 
Date:
 
23 March 2023
 
By:
 
/s/
 
Torgrim Reitan
 
 
Name:
 
Torgrim Reitan
Title:
 
Executive Vice President and Chief Financial Officer
 
The foregoing certification is being furnished solely pursuant to section 906 of the Sarbanes-Oxley Act of
 
2002 (subsections (a) and
(b) of section 1350, chapter 63 of title 18, United States Code) and is not being
 
filed as part of the Report or as a separate disclosure
document.
 
A signed original of this written statement required by section 906 has been provided to
 
the Company and will be retained by the
Company and furnished to the Securities and Exchange Commission or its staff upon request.
 
Consent of Independent Registered Public Accounting Firm
We consent to the incorporation by reference in the following Registration Statements:
 
(1)
 
Registration Statement (Form F-3 No. 333-239808) of Equinor ASA,
(2)
 
Registration Statement (Form F-3 No. 333-239808-01) of Equinor Energy AS,
(3)
 
Registration Statement (Form F-3 No. 333-239808-02) of Equinor US Capital LLC, and
(4)
 
Registration Statement (Form S-8 No. 333-262601) pertaining to the Employee Share Purchase Plan of
Equinor US Holdings Inc
of our reports dated 14 March 2023, with respect to the consolidated financial statements of Equinor ASA and the
effectiveness of internal control over financial reporting of Equinor ASA included in this Annual Report (Form 20-F) of Equinor
ASA for the year ended 31 December 2022.
/s/ Ernst & Young AS
Stavanger, Norway
23 March 2023
DeGolyer
 
and
 
MacNaughton
5001
 
Spring
 
Valley
 
Road
Suite
 
800
 
Eas
t
Dallas,
 
Texas
 
75244
March 20, 2023
Equinor ASA
Forusbeen 50
N-4035 Stavanger
Norway
Ladies and Gentlemen:
We hereby
 
consent to
 
the references
 
to DeGolyer
 
and MacNaughton
 
contained
in
 
the
 
section
 
entitled
 
“Operational
 
Performance;
 
Proved
 
Oil
 
and
 
Gas
 
Reserves;
Preparation of reserves estimates; DeGolyer and
 
MacNaughton report” of the Exhibit
15.5
 
Oil
 
and Gas
 
Reserves Report
 
to
 
Form
 
20-F
 
for
 
the
 
year
 
ended
 
December 31,
2022, of
 
Equinor ASA (the
 
Form 20-F), to
 
the inclusion
 
of our
 
report of
 
third party
 
dated
February 21, 2023,
 
concerning our independent
 
evaluation, as of
 
December 31, 2022,
of certain
 
properties in
 
which Equinor
 
ASA has
 
represented it
 
holds an
 
interest (our
Report of
 
Third Party),
 
which is
 
included as
 
an exhibit
 
to the
 
Form 20-F,
 
and to
 
the
incorporation
 
by
 
reference
 
thereof
 
of
 
our
 
Report
 
of
 
Third
 
Party
 
in
 
the
 
Registration
Statements
 
on
 
Form
 
S-8
 
(File Nos.
 
333-121382,
 
333-168426,
 
and
 
333-262601)
pertaining to the Equinor US Holdings Inc. Employee Share Purchase Plan
 
and in the
Registration
 
Statement
 
on
 
Form
 
F-3
 
(File No.
 
333-239808)
 
of
 
Equinor
 
ASA
 
and
Equinor Energy AS.
Very truly yours,
/s/ DeGolyer and MacNaughton
DeGOLYER and MacNAUGHTON
Texas
 
Registered Engineering Firm F-
716
DeGolyer
 
and
 
MacNaughton
5001
 
Spring
 
Valley
 
Road
Suite
 
800
 
Eas
t
Dallas,
 
Texas
 
75244
February 21, 2023
Equinor ASA
Forusbeen 50
N-4035 Stavanger
Norway
Ladies and Gentlemen:
Pursuant
 
to
 
your
 
request,
 
this
 
report
 
of
 
third
 
party
 
presents
 
an
 
independent
evaluation,
 
as
 
of
 
December
 
31,
 
2022,
 
of
 
the
 
estimated
 
net
 
proved
 
oil,
 
condensate,
liquefied petroleum gas (LPG), and sales gas reserves of
 
certain properties (Table
 
1)
in which Equinor
 
ASA (Equinor)
 
has represented it
 
holds an interest.
 
This evaluation
was completed on February
 
21, 2023. Equinor has represented that
 
these properties
account
 
for
 
100
 
percent,
 
on
 
a
 
net
 
equivalent
 
barrel
 
basis,
 
of
 
Equinor’s
 
net
 
proved
reserves
 
as
 
of
 
December
 
31,
 
2022,
 
and
 
that
 
Equinor’s
 
estimates
 
of
 
net
 
proved
reserves have been prepared in accordance with the reserves definitions of
 
Rules 4–
10(a)
(1)–(32) of Regulation
 
S–X of the
 
United States Securities
 
and Exchange Commission
(SEC). It is
 
our opinion that the
 
procedures and methodologies employed by
 
Equinor
for the preparation of its proved reserves estimates
 
as of December 31, 2022, comply
with the current
 
requirements of the SEC.
 
We have reviewed
 
information provided to
us by
 
Equinor that
 
it represents
 
to be
 
Equinor’s estimates
 
of the
 
net reserves,
 
as of
December 31,
 
2022, for
 
the same
 
properties as
 
those which
 
we have
 
independently
evaluated.
 
This
 
report
 
was
 
prepared
 
in
 
accordance
 
with
 
guidelines
 
specified
 
in
Item 1202 (a)(8)
 
of Regulation
 
S–K and
 
is to
 
be used
 
for inclusion
 
in certain
 
SEC filings
by Equinor.
Reserves estimated
 
herein are
 
expressed as
 
net reserves
 
as represented by
Equinor and
 
as estimated
 
by DeGolyer
 
and MacNaughton.
 
Gross reserves
 
are defined
as the total estimated petroleum
 
remaining to be produced from these
 
properties after
December 31,
 
2022. Net
 
reserves are
 
defined as
 
that
 
portion of
 
the
 
gross reserves
attributable to the
 
interests held by
 
Equinor after deducting
 
all interests held
 
by others.
 
2
DeGolyer and MacNaughton
Estimates of reserves should be regarded
 
only as estimates that may change
as further production
 
history and
 
additional information
 
become available.
 
Not only are
such
 
estimates
 
based
 
on
 
that
 
information
 
which
 
is
 
currently
 
available,
 
but
 
such
estimates are
 
also subject
 
to the uncertainties
 
inherent in
 
the application
 
of judgmental
factors in interpreting such information.
Information used
 
in the
 
preparation of
 
this report
 
was obtained
 
from Equinor.
In the preparation of this report we have relied, without independent
 
verification, upon
information furnished
 
by Equinor
 
with respect
 
to the
 
property interests
 
being evaluated,
production from such properties, current costs of operation
 
and development, current
prices for production, agreements relating
 
to current and future operations and
 
sale of
production, and
 
various other
 
information and
 
data that
 
were accepted
 
as represented.
A field examination was not considered necessary for the purposes of
 
this report.
Definition of Reserves
Petroleum reserves estimated by Equinor and by us included in this report are
classified
 
as
 
proved.
 
Only
 
proved
 
reserves
 
have
 
been
 
evaluated
 
for
 
this
 
report.
Reserves classifications
 
used by
 
Equinor and
 
by us
 
in this
 
report are
 
in accordance
with the reserves definitions of Rules 4–10(a) (1)–(32) of Regulation S–X of the SEC.
Reserves
 
are
 
judged
 
to
 
be
 
economically
 
producible
 
in
 
future
 
years
 
from
 
known
reservoirs
 
under
 
existing
 
economic
 
and
 
operating
 
conditions
 
and
 
assuming
continuation
 
of
 
current
 
regulatory
 
practices
 
using
 
known
 
production
 
methods
 
and
equipment. In
 
the analyses
 
of production-decline
 
curves, reserves
 
were estimated
 
only
to
 
the
 
limit
 
of
 
economic
 
rates
 
of
 
production
 
under
 
existing
 
economic
 
and
 
operating
conditions
 
using
 
prices
 
and
 
costs
 
consistent
 
with
 
the
 
effective
 
date
 
of
 
this
 
report,
including
 
consideration
 
of
 
changes
 
in
 
existing
 
prices
 
provided
 
only
 
by
 
contractual
arrangements
 
but
 
not
 
including
 
escalations
 
based
 
upon
 
future
 
conditions.
 
The
petroleum reserves are classified
 
as follows:
Proved oil
 
and gas
 
reserves
 
– Proved
 
oil and
 
gas reserves
 
are those
quantities
 
of
 
oil
 
and
 
gas,
 
which,
 
by
 
analysis
 
of
 
geoscience
 
and
engineering
 
data,
 
can
 
be
 
estimated
 
with
 
reasonable
 
certainty
 
to
 
be
economically
 
producible—from
 
a
 
given
 
date
 
forward,
 
from
 
known
reservoirs, and
 
under existing
 
economic conditions,
 
operating methods,
and
 
government
 
regulations—prior
 
to
 
the
 
time
 
at
 
which
 
contracts
providing
 
the
 
right
 
to
 
operate
 
expire,
 
unless
 
evidence
 
indicates
 
that
renewal
 
is
 
reasonably
 
certain,
 
regardless
 
of
 
whether
 
deterministic
 
or
probabilistic methods are
 
used for the
 
estimation. The project
 
to extract
the
 
hydrocarbons
 
must
 
have
 
commenced
 
or
 
the
 
operator
 
must
 
be
reasonably certain
 
that it will
 
commence the project
 
within a
 
reasonable
time.
3
DeGolyer and MacNaughton
(i) The area of the reservoir considered as proved includes:
(A) The area identified by drilling
 
and limited by fluid contacts, if
any, and (B)
 
Adjacent undrilled
 
portions of
 
the reservoir
 
that can,
with reasonable
 
certainty, be judged
 
to be
 
continuous with
 
it and
to
 
contain
 
economically
 
producible
 
oil
 
or
 
gas
 
on
 
the
 
basis
 
of
available geoscience and engineering data.
(ii) In the absence of data on
 
fluid contacts, proved quantities in
a reservoir are limited
 
by the lowest known
 
hydrocarbons (LKH)
as seen
 
in a
 
well penetration
 
unless geoscience,
 
engineering,
or performance
 
data and
 
reliable technology
 
establishes a
 
lower
contact with reasonable certainty.
(iii) Where direct
 
observation from
 
well penetrations
 
has defined
a highest known oil (HKO) elevation and the potential exists for
an associated gas cap, proved oil reserves may be assigned in
the
 
structurally
 
higher
 
portions
 
of
 
the
 
reservoir
 
only
 
if
geoscience,
 
engineering,
 
or
 
performance
 
data
 
and
 
reliable
technology
 
establish
 
the
 
higher
 
contact
 
with
 
reasonable
certainty.
(iv)
 
Reserves
 
which
 
can
 
be
 
produced
 
economically
 
through
application of improved recovery
 
techniques (including, but not
limited to,
 
fluid injection)
 
are included
 
in the
 
proved classification
when:
(A)
 
Successful
 
testing
 
by
 
a
 
pilot
 
project
 
in
 
an
 
area
 
of
 
the
reservoir with properties
 
no more favorable than
 
in the reservoir
as a
 
whole, the
 
operation of
 
an installed
 
program in
 
the reservoir
or
 
an
 
analogous
 
reservoir,
 
or
 
other
 
evidence
 
using
 
reliable
technology
 
establishes
 
the
 
reasonable
 
certainty
 
of
 
the
engineering
 
analysis
 
on
 
which
 
the
 
project
 
or
 
program
 
was
based; and (B) The
 
project has been approved
 
for development
by
 
all
 
necessary
 
parties
 
and
 
entities,
 
including
 
governmental
entities.
(v)
 
Existing
 
economic
 
conditions
 
include
 
prices
 
and
 
costs
 
at
which
 
economic
 
producibility
 
from
 
a
 
reservoir
 
is
 
to
 
be
determined.
 
The
 
price
 
shall
 
be
 
the
 
average
 
price
 
during
 
the
12-month period prior
 
to the ending
 
date of the
 
period covered
by the report, determined as an unweighted arithmetic average
4
DeGolyer and MacNaughton
of
 
the
 
first-day-of-the-month
 
price
 
for
 
each
 
month
 
within
 
such
period, unless prices are
 
defined by contractual arrangements,
excluding escalations based upon future conditions.
Developed oil and gas
 
reserves
 
– Developed oil and
 
gas reserves are
reserves of any category that can be expected to be recovered:
(i) Through existing wells
 
with existing equipment
 
and operating
methods
 
or
 
in
 
which
 
the
 
cost
 
of
 
the
 
required
 
equipment
 
is
relatively minor compared to the cost of a new well; and
(ii)
 
Through
 
installed
 
extraction
 
equipment
 
and
 
infrastructure
operational at the time of the reserves estimate if the extraction
is by means not involving a well.
Undeveloped oil and gas reserves
 
–
Undeveloped oil and gas
 
reserves
are
 
reserves of
 
any category
 
that are
 
expected to
 
be recovered
 
from
new wells on
 
undrilled acreage,
 
or from existing
 
wells where
 
a relatively
major expenditure is required for recompletion.
(i)
 
Reserves
 
on
 
undrilled
 
acreage
 
shall
 
be
 
limited
 
to
 
those
directly
 
offsetting
 
development
 
spacing
 
areas
 
that
 
are
reasonably certain of
 
production when drilled,
 
unless evidence
using
 
reliable
 
technology
 
exists
 
that
 
establishes
 
reasonable
certainty of economic producibility at greater distances.
(ii) Undrilled locations can be classified as having undeveloped
reserves only
 
if a
 
development
 
plan has
 
been adopted
 
indicating
that they are
 
scheduled to
 
be drilled within
 
five years, unless
 
the
specific circumstances justify a longer time.
(iii)
 
Under
 
no
 
circumstances
 
shall
 
estimates
 
for
 
undeveloped
reserves be attributable to any
 
acreage for which an
 
application
of
 
fluid
 
injection
 
or
 
other
 
improved
 
recovery
 
technique
 
is
contemplated,
 
unless
 
such
 
techniques
 
have
 
been
 
proved
effective
 
by
 
actual
 
projects
 
in
 
the
 
same
 
reservoir
 
or
 
an
analogous
 
reservoir,
 
as
 
defined
 
in
 
[section
 
210.4–10
 
(a)
Definitions],
 
or
 
by
 
other
 
evidence
 
using
 
reliable
 
technology
establishing reasonable certainty.
 
5
DeGolyer and MacNaughton
Methodology and Procedures
Estimates
 
of
 
reserves
 
were
 
prepared
 
by
 
the
 
use
 
of
 
appropriate
 
geologic,
petroleum
 
engineering,
 
and
 
evaluation
 
principles
 
and
 
techniques
 
that
 
are
 
in
accordance with the reserves definitions of Rules 4–10(a) (1)–(32) of Regulation S–X
of
 
the
 
SEC
 
and
 
with
 
practices
 
generally
 
recognized
 
by
 
the
 
petroleum
 
industry
 
as
presented in the publication
 
of the Society of
 
Petroleum Engineers entitled
 
“Standards
Pertaining to
 
the Estimating
 
and Auditing
 
of Oil
 
and Gas
 
Reserves Information
 
(revised
June 2019)
 
Approved by the
 
SPE Board on
 
25 June
 
2019” and
 
in Monograph 3
 
and
Monograph
 
4
 
published
 
by
 
the
 
Society
 
of
 
Petroleum
 
Evaluation
 
Engineers.
 
The
method
 
or
 
combination
 
of
 
methods
 
used
 
in
 
the
 
analysis
 
of
 
each
 
reservoir
 
was
tempered
 
by
 
experience
 
with
 
similar
 
reservoirs,
 
stage
 
of
 
development,
 
quality
 
and
completeness of basic data, and production history.
Based on the current stage of field development, production performance, the
development plans
 
provided by
 
Equinor, and analyses
 
of areas
 
offsetting existing
 
wells
with
 
test
 
or
 
production
 
data,
 
reserves
 
were
 
classified
 
as
 
proved.
 
The
 
proved
undeveloped reserves estimates
 
were based on
 
opportunities identified in
 
the plans of
development provided by Equinor.
Equinor
 
has
 
represented
 
that
 
its
 
senior
 
management
 
is
 
committed
 
to
 
the
development plans
 
provided by
 
Equinor and that
 
Equinor has
 
the financial
 
capability
to execute
 
the development
 
plans, including
 
the drilling
 
and completion
 
of wells
 
and
the installation of equipment and facilities.
When applicable, the
 
volumetric method was
 
used to
 
estimate the original
 
oil
in place
 
(OOIP) and
 
original gas
 
in place
 
(OGIP).
 
Structure maps
 
were prepared
 
to
delineate
 
each
 
reservoir,
 
and
 
isopach
 
maps
 
were
 
constructed
 
to
 
estimate
 
reservoir
volume.
 
Electrical
 
logs,
 
radioactivity
 
logs,
 
and
 
other
 
available
 
data
 
were
 
used
 
to
prepare these
 
maps as
 
well as
 
to estimate
 
representative values
 
for porosity
 
and water
saturation.
 
When
 
adequate
 
data
 
were
 
available
 
and
 
when
 
circumstances
 
justified,
material-balance
 
and
 
other
 
engineering
 
methods
 
were
 
used
 
to
 
estimate
 
OOIP
 
and
OGIP.
For those
 
fields where
 
the volumetric
 
method was
 
applied, estimates
 
of ultimate
recovery
 
were
 
obtained
 
after
 
applying
 
recovery
 
factors
 
to
 
OOIP
 
and
 
OGIP.
 
These
recovery
 
factors
 
were
 
based
 
on
 
consideration
 
of
 
the
 
type
 
of
 
energy
 
inherent
 
in
 
the
reservoirs, analyses
 
of the
 
petroleum, the
 
structural positions
 
of the
 
reservoirs, and
 
the
production
 
histories.
 
When
 
applicable,
 
material-balance
 
and
 
other
 
engineering
methods
 
were
 
used
 
to
 
estimate
 
recovery
 
factors
 
based
 
on
 
an
 
analysis
 
of
 
reservoir
pressure and reservoir fluid properties.
6
DeGolyer and MacNaughton
For depletion-type reservoirs or those whose performance disclosed a
 
reliable
decline
 
in
 
producing-rate
 
trends
 
or
 
other
 
diagnostic
 
characteristics,
 
reserves
 
were
estimated
 
by
 
the
 
application
 
of
 
appropriate
 
decline-curve
 
or
 
other
 
performance
relationships. In
 
the analyses
 
of production
 
decline curves,
 
reserves were
 
estimated
only to the
 
limits of economic
 
production as defined under
 
the Definition of
 
Reserves
heading of this report or to the limit of production licenses as appropriate.
For
 
the
 
evaluation
 
of
 
unconventional
 
reservoirs,
 
a
 
performance-based
methodology integrating the appropriate
 
geology and petroleum
 
engineering data was
utilized
 
for
 
this
 
report.
 
Performance-based
 
methodology
 
primarily
 
includes
(1) production diagnostics,
 
(2) decline-curve
 
analysis, and
 
(3) model-based
 
analysis (if
necessary,
 
based on availability
 
of data). Production
 
diagnostics include data
 
quality
control,
 
identification of
 
flow
 
regimes,
 
and
 
characteristic well
 
performance behavior.
These analyses were performed for all well groupings (or type-curve areas).
Characteristic
 
rate-decline
 
profiles
 
from
 
diagnostic
 
interpretation
 
were
translated
 
to
 
modified
 
hyperbolic
 
rate
 
profiles,
 
including
 
one
 
or
 
multiple
 
b-exponent
values
 
followed
 
by
 
an
 
exponential
 
decline.
 
Based
 
on
 
the
 
availability
 
of
 
data,
model-based analysis
 
may be
 
integrated to
 
evaluate long-term
 
decline behavior,
 
the
effect of dynamic
 
reservoir and
 
fracture parameters
 
on well
 
performance, and
 
complex
situations sourced by the nature of unconventional reservoirs.
In certain
 
cases, reserves
 
were estimated
 
by incorporating
 
elements of
 
analogy
with similar wells or reservoirs for which more complete data were available.
Data
 
provided
 
by
 
Equinor
 
from
 
wells
 
drilled
 
through
 
October
 
31,
 
2022,
 
and
made available
 
for this evaluation
 
were used
 
to prepare
 
the reserves
 
estimates herein.
These
 
reserves
 
estimates
 
were
 
based
 
on
 
consideration
 
of
 
monthly
 
production
 
data
available
 
for
 
certain
 
properties
 
only
 
through
 
October
 
2022.
 
Estimated
 
cumulative
production, as
 
of December
 
31, 2022, was
 
deducted from
 
the estimated
 
gross ultimate
recovery to estimate gross
 
reserves. This required
 
that production be estimated
 
for up
to 2 months.
Oil
 
and
 
condensate reserves
 
estimated herein
 
are those
 
to
 
be recovered
 
by
normal field
 
separation. LPG
 
reserves estimated
 
herein consist
 
primarily of
 
propane
and
 
butane
 
fractions
 
and
 
are
 
the
 
result
 
of
 
low-temperature
 
plant
 
processing.
 
Oil,
condensate,
 
and
 
LPG
 
reserves
 
included
 
in
 
this
 
report
 
are
 
expressed
 
in
 
millions
 
of
barrels (10
6
bbl). In these estimates, 1 barrel equals 42 United States gallons.
Gas
 
quantities
 
estimated
 
herein
 
are
 
expressed
 
as
 
sales
 
gas.
 
Sales
 
gas
 
is
defined as
 
the total
 
gas to
 
be produced
 
from the
 
reservoirs after
 
reduction for
 
shrinkage
from field or
 
platform handling, separation, processing
 
(including liquid removal), fuel
 
7
DeGolyer and MacNaughton
usage, flaring,
 
reinjection, pipeline
 
losses, and
 
onshore processing
 
measured at
 
the
point
 
of
 
delivery.
 
Gas
 
reserves
 
estimated
 
herein
 
are
 
reported
 
as
 
sales
 
gas.
 
Gas
quantities are expressed at a temperature base of 15.6 degrees Celsius (°C) and at a
pressure
 
base
 
of
 
14.696
 
pounds
 
per
 
square
 
inch
 
absolute
 
(psia).
 
Gas
 
quantities
included in this report are expressed in billions of cubic feet (10
9
ft
3
).
Gas quantities are identified by the type
 
of reservoir from which the gas
 
will be
produced. Nonassociated gas
 
is gas
 
at initial
 
reservoir conditions with
 
no oil
 
present
in the reservoir. Associated gas includes both gas-cap gas and solution gas. Gas-cap
gas is gas at initial reservoir conditions and is in communication with an underlying
 
oil
zone.
 
Solution
 
gas
 
is
 
gas
 
dissolved
 
in
 
oil
 
at
 
initial
 
reservoir
 
conditions.
 
The
 
gas
quantities
 
estimated
 
herein
 
consist
 
of
 
both
 
associated
 
and
 
nonassociated
 
gas
reserves.
At the request of
 
Equinor, sales gas reserves estimated
 
herein were converted
to
 
oil
 
equivalent
 
using
 
an
 
energy
 
equivalent
 
factor
 
of
 
5,612.1
 
cubic
 
feet
 
of
 
gas
 
per
1 barrel of oil equivalent.
Primary Economic Assumptions
This
 
report
 
has
 
been
 
prepared
 
using
 
initial
 
prices,
 
expenses,
 
and
 
costs
provided
 
by
 
Equinor
 
in
 
United
 
States
 
dollars
 
(U.S.$).
 
Future
 
prices
 
were
 
estimated
using
 
guidelines
 
established
 
by
 
the
 
SEC
 
and
 
the
 
Financial
 
Accounting
 
Standards
Board
 
(FASB).
 
The
 
following
 
economic
 
assumptions
 
were
 
used
 
for
 
estimating
 
the
reserves reported herein:
Oil, Condensate,
 
and LPG Prices
Equinor
 
has
 
represented
 
that
 
the
 
oil,
 
condensate,
 
and
 
LPG
prices
 
were
 
based
 
on
 
a
 
reference
 
price,
 
calculated
 
as
 
the
unweighted
 
arithmetic
 
average
 
of
 
the
 
first-day-of-the-month
price for each month
 
within the 12-month
 
period prior to the
 
end
of the reporting period, unless prices are defined
 
by contractual
agreements. Equinor supplied differentials by field
 
to a Brent oil
reference price
 
of U.S.$101.24
 
per barrel
 
and the
 
prices were
held constant
 
thereafter.
 
The volume-weighted
 
average prices
attributable to
 
the
 
estimated proved
 
reserves over
 
the
 
lives of
the
 
properties
 
were
 
U.S.$100.30
 
per
 
barrel
 
of
 
oil,
 
U.S.$90.79
per barrel of condensate, and U.S.$56.23 per barrel of LPG.
Gas Prices
8
DeGolyer and MacNaughton
Equinor has also
 
represented that
 
the gas
 
prices were
 
based on
a
 
reference
 
price,
 
calculated
 
as
 
the
 
unweighted
 
arithmetic
average of
 
the first-day-of-the-month
 
price for
 
each month
 
within
the
 
12-month
 
period
 
prior
 
to
 
the
 
end
 
of
 
the
 
reporting
 
period,
unless
 
prices
 
are
 
defined
 
by
 
contractual
 
agreements.
 
A
significant
 
quantity
 
of
 
the
 
gas
 
sold
 
by
 
Equinor
 
is
 
subject
 
to
contract prices,
 
and the
 
range of
 
such prices
 
is varied.
 
Where
appropriate,
 
Equinor
 
supplied
 
differentials
 
by
 
field
 
to
 
a
 
Title
Transfer Facility
 
gas price
 
index reference
 
price of
 
U.S.$36.35
per million
 
Btu and
 
the prices
 
were held
 
constant thereafter. The
volume-weighted
 
average
 
price
 
attributable
 
to
 
the
 
estimated
proved reserves over
 
the lives of
 
the properties was
 
U.S.$30.66
per million Btu of gas.
Operating Expenses,
 
Capital Costs, and Abandonment Costs
Estimates
 
of
 
operating
 
expenses
 
and
 
future
 
capital
expenditures,
 
provided
 
by
 
Equinor
 
and
 
based
 
on
 
existing
economic
 
conditions,
 
were
 
held
 
constant
 
for
 
the
 
lives
 
of
 
the
properties. In
 
certain cases,
 
future
 
expenditures, either
 
higher
or
 
lower
 
than
 
current
 
expenditures,
 
may
 
have
 
been
 
used
because of anticipated changes in
 
operating conditions, but no
general escalation
 
that might
 
result from
 
inflation was
 
applied.
Abandonment costs, which are those costs associated with the
removal of
 
equipment, plugging
 
of
 
wells,
 
and reclamation
 
and
restoration associated with
 
the abandonment, were
 
provided by
Equinor
 
for
 
all
 
properties
 
and
 
were
 
not
 
adjusted
 
for
 
inflation.
Abandonment
 
costs
 
herein
 
are
 
inclusive
 
of
 
costs
 
incurred
 
for
existing
 
wells
 
and
 
facilities
 
as
 
well
 
as
 
those
 
for
 
future
development
 
associated
 
with
 
the
 
proved
 
reserves
 
estimated
herein.
 
Operating
 
expenses,
 
capital
 
costs,
 
and
 
abandonment
costs were
 
considered in
 
determining the
 
economic viability
 
of
the undeveloped reserves estimated herein.
In
 
our
 
opinion,
 
the
 
information
 
relating
 
to
 
estimated
 
proved
 
reserves
 
of
 
oil,
condensate,
 
LPG,
 
and
 
sales
 
gas
 
contained
 
in
 
this
 
report
 
has
 
been
 
prepared
 
in
accordance
 
with
 
Paragraphs
 
932-235-50-4,
 
932-235-50-6,
 
932-235-50-7,
 
and
932-235-50-9 of
 
the Accounting Standards
 
Update 932-235-50,
Extractive Industries
–
 
Oil
 
and
 
Gas
 
(Topic
 
932):
 
Oil
 
and
 
Gas
 
Reserve
 
Estimation
 
and
 
Disclosures
(January 2010)
 
of
 
the
 
FASB
 
and
 
Rules
 
4–10(a)
 
(1)–(32)
 
of
 
Regulation
 
S–X
 
and
Rules 302(b), 1201, 1202(a)
 
(1), (2), (3),
 
(4), (8), and
 
1203(a) of Regulation
 
S–K of the
9
DeGolyer and MacNaughton
SEC; provided,
 
however, that estimates
 
of proved
 
developed and
 
proved undeveloped
reserves are not presented at the beginning of the year.
To the extent the above-enumerated
 
rules, regulations,
 
and statements
 
require
determinations
 
of
 
an
 
accounting
 
or
 
legal
 
nature,
 
we,
 
as
 
engineers,
 
are
 
necessarily
unable
 
to
 
express
 
an
 
opinion
 
as
 
to
 
whether
 
the
 
above-described
 
information
 
is
 
in
accordance therewith or sufficient therefor.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
10
DeGolyer and MacNaughton
Summary of Conclusions
DeGolyer and MacNaughton has performed
 
an independent evaluation of the
extent of
 
the
 
estimated net
 
proved oil,
 
condensate, LPG,
 
and sales
 
gas reserves
 
of
certain properties in
 
which Equinor
 
has represented it
 
holds an interest.
 
Equinor has
represented
 
that
 
its
 
estimated
 
net
 
proved
 
reserves
 
attributable
 
to
 
the
 
evaluated
properties were
 
based on
 
the definition
 
of proved
 
reserves of
 
the SEC.
 
Equinor has
represented that
 
its estimates of
 
the net
 
proved reserves,
 
as of
 
December 31, 2022,
attributable to these properties, which represent 100 percent of Equinor’s
 
reserves on
a
 
net
 
equivalent
 
basis,
 
are
 
summarized
 
as
 
follows,
 
expressed
 
in
 
millions
 
of
 
barrels
(10
6
bbl), billions of cubic feet
 
(10
9
ft
3
), and millions of barrels
 
of oil equivalent (10
6
boe):
Estimated by Equinor
Net Proved Reserves as of December 31, 2022
Oil
(10
6
bbl)
Condensate
(10
6
bbl)
LPG
(10
6
bbl)
Sales
Gas
(10
9
ft
3
)
Oil
Equivalent
(10
6
boe)
Total
 
Proved
2,211.1
36.7
280.0
14,946.1
5,191.0
Note: Sales gas reserves estimated herein were converted to oil equivalent using an
energy equivalent factor of 5,612.1 cubic feet of gas per 1 barrel of oil equivalent.
DeGolyer and MacNaughton’s independent estimates of Equinor’s net
 
proved
reserves,
 
as
 
of
 
December
 
31,
 
2022,
 
attributable
 
to
 
the
 
evaluated
 
properties
 
were
based on the definition
 
of proved reserves
 
of the SEC
 
and are summarized
 
as follows,
expressed in
 
millions of
 
barrels (10
6
bbl), billions
 
of cubic
 
feet (10
9
ft
3
), and
 
millions of
barrels of oil equivalent (10
6
boe):
Estimated by DeGolyer and MacNaughton
Net Proved Reserves as of December 31, 2022
Oil
(10
6
bbl)
Condensate
(10
6
bbl)
LPG
(10
6
bbl)
Sales
Gas
(10
9
ft
3
)
Oil
Equivalent
(10
6
boe)
Total
 
Proved
2227.1
84.0
289.2
15,252.1
5,318.0
Note: Sales gas reserves estimated herein were converted to oil equivalent using an
energy equivalent factor of 5,612.1 cubic feet of gas per 1 barrel of oil equivalent.
 
11
DeGolyer and MacNaughton
Regnald A. Boles, P.E.
 
Executive Vice President
DeGolyer and MacNaughton
In comparing
 
the detailed
 
net proved
 
reserves estimates
 
prepared by
 
DeGolyer
and
 
MacNaughton
 
and
 
by
 
Equinor,
 
differences
 
have
 
been
 
found,
 
both
 
positive
 
and
negative, resulting
 
in an
 
aggregate difference
 
of 2.4
 
percent when
 
compared on
 
the
basis of net equivalent barrels. It is
 
DeGolyer and MacNaughton’s opinion that
 
the net
proved
 
reserves
 
estimates
 
prepared
 
by
 
Equinor
 
on
 
the
 
properties
 
evaluated
 
and
referred to above,
 
when compared
 
on the
 
basis of
 
net equivalent
 
barrels, in
 
aggregate,
do not differ materially from those prepared by DeGolyer and MacNaughton.
While the oil and gas industry may be subject to regulatory changes from time
to time that could affect an industry participant’s ability to recover its reserves, we are
not aware
 
of any such
 
governmental actions which would
 
restrict the recovery
 
of the
December 31, 2022, estimated reserves.
DeGolyer
 
and
 
MacNaughton
 
is
 
an
 
independent
 
petroleum
 
engineering
consulting firm that
 
has been providing
 
petroleum consulting services
 
throughout the
world since
 
1936. DeGolyer
 
and MacNaughton
 
does not
 
have any
 
financial interest,
including stock ownership,
 
in Equinor.
 
Our fees were
 
not contingent on the
 
results of
our
 
evaluation.
 
This
 
letter
 
report
 
has
 
been
 
prepared
 
at
 
the
 
request
 
of
 
Equinor.
DeGolyer
 
and
 
MacNaughton
 
has
 
used
 
all
 
assumptions,
 
data,
 
procedures,
 
and
methods that it considers necessary and appropriate to prepare this
 
report.
Submitted,
DeGOLYER and MacNAUGHTON
Texas
 
Registered Engineering Firm F-
716
 
 
DeGolyer and MacNaughton
Regnald A. Boles, P.E.
 
Executive Vice President
DeGolyer and MacNaughton
CERTIFICATE of QUALIFICATION
I,
 
Regnald
 
A.
 
Boles,
 
Petroleum
 
Engineer
 
with
 
DeGolyer
 
and
 
MacNaughton,
5001 Spring Valley Road, Suite 800
 
East, Dallas,
 
Texas, 75244 U.S.A., hereby certify:
1.
 
That I
 
am an
 
Executive Vice
 
President with
 
DeGolyer and
 
MacNaughton, which
firm
 
did
 
prepare
 
the
 
report
 
of
 
third
 
party
 
addressed
 
to
 
Equinor
 
dated
February 21, 2023, and
 
that
 
I,
 
as Executive
 
Vice
 
President, was
 
responsible
for the preparation of this report of third party.
2.
 
That I attended Texas A&M University,
 
and that I graduated with a Bachelor
 
of
Science
 
degree
 
in
 
Petroleum
 
Engineering
 
in
 
the
 
year
 
1983;
 
that
 
I
 
am
 
a
Registered Professional Engineer in
 
the State of Texas; that I am a member of
the
 
Society
 
of
 
Petroleum
 
Engineers;
 
that
 
I
 
am
 
a
 
member
 
of
 
the
 
European
Association
 
of
 
Geoscientists
 
and
 
Engineers;
 
and
 
that
 
I
 
have
 
in
 
excess
 
of
39 years of experience in oil and gas reservoir studies and evaluations.
 
DeGolyer and MacNaughton
TABLE 1
Country
Field
Algeria
In Amenas
In Salah
Angola
Acacia
Cravo
Dalia
Girassol
Kizomba A
Kizomba B
Lirio
Marte
Mondo
Orquidea-Violeta
Perpetua-Hortensia
Plutao
Rosa
Saturno
Saxi-Batuque
Venus
Zinia
Argentina
Bandurria Sur
Azerbaijan
Azeri-Chirag-Gunashli
Azeri-Chirag-Gunashli-ACE
Brazil
Bacalhau Concession
Bacalhau PSA
Peregrino
Roncador
Canada
Hebron
Hibernia
Hibernia Southern Extension
Republic of Ireland
Corrib
Libya
Mabruk
Murzuq
Nigeria
Agbami
 
 
DeGolyer and MacNaughton
TABLE 1
 
–
(Continued)
Country
Field
Norway
Aasta Hansteen
Aerfugl North
Alve
Andvare
Asgard
Asterix
Bauge
Berling
Blabjorn
Breidablikk
Byrding
Enoch
Fram
 
Fram H-North
Fulla
Gimle
Gina Krog
Goliat
Grane
Gudrun
 
Gullfaks Area
Gungne
Halten East
Hanz
Heidrun
 
Hyme
Idun North
Ivar Aasen
Johan Castberg
Johan Sverdrup
Johan Sverdrup Phase 2
Krafla
Kristin
Kristin South Phase 1
Kvitebjorn
 
Lille Prinsen
Martin Linge
Marulk
Mikkel
Morvin
Njord
Norne
Ormen Lange
Ormen Lange Phase 3
Orn
Oseberg
Oseberg East
Oseberg South
Sigyn
Skarv
TABLE 1
–
(Continued)
Country
Field
DeGolyer and MacNaughton
Norway –
(Continued)
Skuld
Sleipner East
Sleipner West
Snohvit
 
Snorre
Statfjord
Statfjord East
Statfjord North
Svalin
Sygna
Tordis
 
Trestakk
Troll
 
Tune
Tyrihans
Urd
Utgard
Valemon
Verdande
Veslefrikk
Vigdis
Visund
Visund South
United Kingdom
Barnacle
Mariner
Statfjord
United States
APB North Non-Op
APB Op
APB South Non-Op
Big Foot
Caesar-Tonga
Heidelberg
Jack
Julia
St. Malo
Stampede
Tahiti
Titan
Vito
Equinor, Annual Report on Form 20-F 2022
 
1
exhibit154p2i0
 
 
 
 
 
 
 
 
 
 
2
 
Equinor, Annual Report on Form 20-F 2022
 
2022
 
Integrated
 
Annual
 
Report
exhibit154p3i0
Equinor, Annual Report on Form 20-F 2022
 
3
We are Equinor
 
Our ambition is to be a leading company in the energy
transition. We aim to create value through the opportunities the
energy transition brings, breaking new industrial ground by
building on our 50 years of experience.
 
We energise the lives
 
of 170 million people.
 
Every day.
 
Troll A. Norwegian continental
shelf
exhibit154p4i0 exhibit154p4i1 exhibit154p4i3 exhibit154p4i5 exhibit154p4i7 exhibit154p4i9 exhibit154p4i11 exhibit154p4i13 exhibit154p4i15 exhibit154p4i17 exhibit154p4i19 exhibit154p4i21 exhibit154p4i23 exhibit154p4i25 exhibit154p4i27 exhibit154p4i29 exhibit154p4i31
4
 
Equinor, Annual Report on Form 20-F 2022
 
Equinor is an energy company,
 
the largest oil and gas operator in Norway,
 
one of the world’s largest offshore
operators, and a growing force in renewables and low
 
carbon solutions. Present in around 30 countries with
approximately 22,000 employees, we provide reliable
 
energy for societies worldwide and aim to be a leading
company in the energy transition with the ambition to become
 
a net-zero company by 2050.
Key figures 2022.
 
 
2,039
 
mboe
per day
 
- oil and gas equity production
0.4
SIF - serious incident
 
frequency
 
(per million hours worked)
1,649
 
GWh
 
Renewable power generation,
Equinor share
2,661
 
GWh
 
Total
 
power generation,
Equinor share
+8%
gas production
from the NCS
Gas production increased
in response to the energy
security crisis in Europe
2.5
TRIF - total recordable
incident frequency
(per million hours worked)
Always safe,
high value,
 
low carbon
6.9
 
CO
2
intensity
 
for the upstream oil and gas portfolio
 
(operated 100%, kg CO
2
per boe)
USD
52.2
billion
 
current income tax
expense
USD
13.7
billion
Capital distribution
including dividends
 
and share buy-backs
21,936
 
Employees
 
across around
 
30 countries
Equinor, Annual Report on Form 20-F 2022
 
5
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
6
 
Equinor, Annual Report on Form 20-F 2022
 
(in USD million)
2022
2021
Total revenues and other income
150,806
90,924
Net operating income
78,811
33,663
Net income
28,744
8,576
Effective tax rate
63.4%
72.8%
Adjusted earnings*
74,940
33,486
Adjusted earnings after tax*
22,691
10,042
Free cash flow before capital distribution (in USD
billion)*
32.1
27.1
Return on capital employed, adjusted*
55.2%
22.7%
Key Figures – Segment performance
 
E&P Norway
E&P International
E&P USA
Financial information
2022
2021
2022
2021
2022
2021
Total revenue and other income
75,930
39,386
7,431
5,566
5,523
4,149
Total operating expenses
8,315
8,915
4,183
5,237
1,501
2,998
Net operating income
67,614
30,471
3,248
329
4,022
1,150
Adjusted earnings/(loss)*
 
66,260
29,099
3,806
2,028
2,957
1,297
Additions to PP&E, intangibles
and equity accounted investments
4,922
4,943
2,623
1,834
764
690
Operational information
2022
2021
2022
2021
2022
2021
E&P equity liquid and gas
production (mboe/day)
1,387
1,364
328
342
324
373
E&P entitlement liquid and gas
production (mboe/day)
1,387
1,364
235
246
279
321
Average liquids price (USD/bbl)
97.5
67.6
92.0
67.6
81.0
58.3
Average internal gas price
(USD/mmbtu)
31.22
14.43
5.55
2.89
MMP
REN
Financial information
2022
2021
2022
2021
Total revenue and other income
148,105
87,393
185
1,411
Total operating expenses
144,493
86,230
269
166
Net operating income
3,612
1,163
(84)
1,245
Adjusted earnings/(loss)*
 
2,253
1,424
(184)
(136)
Additions to PP&E, intangibles
and equity accounted investments
1,212
517
298
458
Operational information
2022
2021
2022
2021
Liquids sales volumes (mmbbl)
740.1
758.4
Natural gas sales Equinor (bcm)
63.3
61.0
Natural gas entitlement sales
Equinor (bcm)
56.1
54.0
Power generation (GWh) Equinor
share
1,012
1,641
1,562
* For items marked with an asterisk throughout this
 
report, see section 5.8 Use and reconciliation of
 
non-GAAP financial measures.
exhibit154p7i0
Equinor, Annual Report on Form 20-F 2022
 
7
Message from the chair and CEO
Equinor’s purpose is turning natural resources into energy for people, and progress for
 
society. 2022 was a year that demonstrated
how important and valuable energy is to society. The invasion of Ukraine and Russia’s weaponisation of energy brought a deep
crisis to a system already in imbalance. It became apparent that security of supply in Europe rests
 
on reliable access to natural gas.
The war continues to impact society and people’s lives. As part of an aligned response to the invasion, Equinor decided
 
on 27
February 2022 to exit Russia.
During last year, the effects of global climate change proved the strong need to act on the goals in the Paris agreement. The energy
sector must innovate to cut emissions and create low-carbon energy systems. We must accelerate investments
 
in renewables,
energy efficiency, and in low-carbon solutions to decarbonise industry and society. But to safeguard a just and inclusive change of
the energy system, we must secure access to affordable and reliable energy. In this context, Equinor is well positioned, as we focus
on providing the energy the world needs while reducing emissions from our own operations
 
and investing in the necessary systemic
change towards net zero.
Geopolitical developments call for a balanced energy transition. More investments in energy production and infrastructure
 
are
needed to reduce the cost of energy, and security of supply and decarbonisation of the sector will be required. Enabling such a
transition calls for longevity and stability of frame conditions. Even within the most ambitious goals
 
of the Paris agreement and the
net-zero scenario of the International Energy Agency, there will still be a need for oil and gas in the 2050 energy mix.
 
A substantial
part of the remaining demand will stem from the need for feedstock for industry and consumer goods
 
to a global population of
around 10 billion people. Low-carbon hydrogen produced from gas has the potential to become an important
 
source of energy in the
future. Equinor’s Energy transition plan, supported by 97.5 percent of our shareholders at the
 
annual general meeting in May 2022,
 
8
 
Equinor, Annual Report on Form 20-F 2022
 
outlines how Equinor will aim to deliver on its ambition to reach net zero by 2050.
In 2022, when it was more important than ever, people working for Equinor stepped up to deliver safe, secure, and reliable
production with low emissions. The serious incident frequency for the company in 2022 was
 
0.4 per million hours worked, a slight
improvement from the previous year, and the lowest frequency ever recorded. We progressed our emissions reduction (scope 1 and
2) by reaching a decline of 31 percent since 2015, taking us towards our ambition of net 50 percent reduction
 
by 2030. In 2022, we
also signed the world’s first commercial agreement on cross-border CO
2
 
transportation and storage together with the joint venture
partners in the Northern Lights project.
During the year, we have reached key milestones to deliver on our strategy through strong project execution. Johan Sverdrup phase
2 on the Norwegian continental shelf started production,
 
adding barrels to a world-class oil field and making our portfolio even more
robust. Peregrino phase 2 in Brazil came on stream in October, adding 250–300 million barrels while halving expected CO
2
emissions per barrel over the field’s remaining lifetime. We generated first power at Hywind Tampen, the world’s first floating wind
farm to power offshore oil and gas platforms. Further, we matured our renewables project portfolio, and won new offshore wind
leases. We aim to emerge as a leading energy player in selected international markets.
Together with partners, suppliers, and authorities, we managed to increase our gas supply to Europe by 8 percent compared to
2021. In total we produced around 2 million boe per day, and 2.7 terawatt hours of power. The CO
2
 
intensity of our production ended
at 6.9 kg CO
2
 
per boe, far below the global average. Our unit production cost for oil and gas was USD
 
6 per barrel, confirming
continued cost control. With cost inflation and continued supply chain disruption, we focus on maintaining
 
cost competitiveness
through the cycles.
Against the backdrop of the energy crisis in Europe natural gas prices rose to levels
 
previously unseen. Our performance and focus
on high production and stable delivery of oil and gas throughout the year resulted in high net
 
operating income of USD 79 billion.
This enabled us to maintain competitive shareholder returns, increasing the dividends and share
 
buybacks during the year. At the
capital markets update in February 2023, we announced a step-up in the capital distribution. We proposed
 
a 50 percent increase in
the ordinary cash dividend for the fourth quarter,
 
to 30 cents per share. In combination with extraordinary dividend and share buy-
back, we expect a total distribution in 2023 of USD 17 billion. In 2022, Equinor also contributed
 
with USD 42.8 billion in taxes from
operations on the Norwegian continental shelf. After costs, taxes, and capital distribution our free
 
cash flow* ended at USD 23.4
billion.
Equinor’s strong performance and results put the company in a robust financial position.
 
We continue to optimise the oil and gas
portfolio, accelerate renewables, and develop low-carbon solutions to deliver on our strategy. The strong cash flow from our oil and
gas business together with our robust balance sheet enable us to continue investing and innovating. We aim to develop and bundle
energy services and products, build new value chains, and invest in infrastructure projects, while delivering
 
healthy and competitive
returns to our shareholders. With our gas reserves and existing infrastructure, we are uniquely
 
positioned to develop low carbon
value chains. In collaboration with governments, industry, and customers, we aim to build markets for hydrogen and carbon capture
and storage to achieve necessary scale. Our strategy and portfolio of producing assets and projects position
 
us well to be a leading
company in the energy transition.
Equinor is in a strong position to create value in the energy transition, by providing affordable, low carbon and
 
secure energy. In
2030 we aim to produce around 2 million barrels of oil and gas per day, and 35-60 TWh of power from renewables
 
annually. In
addition, we are developing capacity for energy storage through batteries and green hydrogen,
 
as well as blue hydrogen and carbon
transport and storage.
We would like to express appreciation of our employees’ strong performance under extraordinary circumstances in 2022.
 
We would
also like to thank Equinor’s shareholders for their continued investment,
 
and our stakeholders for a strong commitment.
Jon Erik Reinhardsen, chair of the board
Anders Opedal, president and CEO
 
Equinor, Annual Report on Form 20-F 2022
 
9
Table of contents
Introduction
Reporting segment performance
We are Equinor
3.1
Optimised oil and gas
Key figures
3.1.1
E&P Norway
Message from the chair and CEO
3.1.2
E&P International
About the report
3.1.3
E&P USA
Equinor in 2022
3.2
High-value growth in renewables (REN)
Progress on our Energy transition plan
3.3
Marketing, midstream and processing (MMP),
including new market opportunities in low carbon solutions
About Equinor and our strategy
3.4
Other group
1.1
This is Equinor
1.2
Our history
Financial statements and notes
1.3
Our business
4.1
Consolidated financial statements of the Equinor group
1.4
Equinor's market perspective
4.2
Parent company financial statements
1.5
Equinor's strategy
1.6
Capital and liquidity management
Additional information
1.7
Sustainability at Equinor
5.1
Board statement on corporate governance
1.8
Governance and risk management
5.2
Risk factors
1.9
Our people - To get there. Together
5.3
Shareholder information
1.10
External relations
5.4
EU taxonomy for sustainable activities
5.5
Production per field
Enterprise level performance
5.6
Additional sustainability information
Performance 2022
5.7
Statements on this report incl. independent
 
auditor reports
2.1
Always safe
5.8
Use and reconciliation of non-GAAP financial measures
2.1.1
Safe and secure operations
5.9
Terms and abbreviations
2.1.2
Protecting nature
5.10
Forward-looking statements
2.1.3
Tackling inequality - Human rights
2.1.4
Tackling inequality - Diversity and inclusion
2.2
High value
Group analysis
2.2.1
Efficient and predictable operations
2.2.2
Profitable portfolio
2.2.3
Value creation for society
2.2.4
Integrity and anti-corruption
2.3
Low carbon
2.3.1
Net zero pathway
2.3.2
Emissions reduction
10
 
Equinor, Annual Report on Form 20-F 2022
 
About the report
 
Equinor publishes an Integrated annual report for 2022
Equinor has the for the full year of 2022 released an Integrated annual report, which combines
 
financial and sustainability reporting
into a single document. This integration acknowledges the increasing importance of sustainability issues to
 
the company's operational
and financial performance and is in accordance with the expectations of our stakeholders. Furthermore,
 
this format aligns with
external frameworks such as the Taskforce on Climate-related Financial Disclosure (TCFD) and upcoming requirements from the
European Union (EU) under the Corporate Sustainability Reporting Directive (CSRD).
This report presents the
●
Board of director’s report (Chapters 0-3 and Chapter 5 excluding sections 5.4, 5.6, 5.9, 5.10)
●
Consolidated financial statements of the Equinor group (section 4.1)
●
Parent company financial statements of Equinor ASA (section 4.2) according to the Norwegian
 
Accounting Act of 1998
●
Board statement on corporate governance according to The Norwegian Code of Practice
 
for Corporate Governance (section 5.1)
●
The company’s sustainability reporting, prepared in accordance with the Global Reporting Initiative (GRI) Standards.
●
Communication on Progress to the UN Global Compact (advanced reporting level)
Other 2022 Reporting published on equinor.com/reports
●
Annual report on Form 20-F
●
Remuneration report, incl. 2021 Remuneration policy
●
Payments to governments
●
Oil and gas reserves report
●
Human rights statement
●
GRI and WEF index
●
UK modern slavery statement
●
Equinor datahub (ESG reporting centre)
This document constitutes the Statutory annual report in accordance with Norwegian requirements for
 
Equinor ASA for the year
ended 31 December 2022. The Integrated annual report is filed with the Norwegian Register of company
 
accounts. Further
information on the boundary conditions for sustainability data can be found in section 5.6 Additional sustainability
 
information.
This document should be read in conjunction with the cautionary statement in section 5.10 Forward-looking
 
statements.
The Integrated annual report may be downloaded from Equinor’s website at www.equinor.com/reports. References in this document
or other documents to Equinor’s website are included as an aid to their location
 
and are not incorporated by reference into this
document.
exhibit154p4i0
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
11
January
Equinor was awarded
26
 
new production licences on
the Norwegian continental shelf (NCS), of which
12
 
as
operator.
February
 
In response to the European security situation,
Equinor stopped investments into Russia and started
the process of exiting from our
Russian joint
ventures.
March
We enabled
increased gas exports
 
to Europe with
adjusted permits and postponed turnaround at
Oseberg,
 
allowing for high production through the
summer months so storage could be replenished.
 
Together with bp, we signed an agreement to
transform New York’s
South Brooklyn Marine
Terminal
 
into a hub for the region’s offshore wind
industry.
April
 
We were awarded operatorships for the development
of a new CO
2
storage facility
 
-
Smeaheia
 
in the North
Sea, with capacity for 20 million tonnes of CO
2
annually.
May
At the annual general meeting, the
Energy transition
plan
 
received support from 97.5% of the voting
shareholders.
We continue to optimise our portfolio. On the NCS
Equinor divested its share of the
Ekofisk
field and a
share in
Martin Linge
.
Together with partners we submitted the plan for
development and operation (PDO) of Halten East, a
subsea development for gas and condensate, tied
back to the
Åsgard field
in the Norwegian Sea.
June
After an extensive programme of repairs and
improvements,
Hammerfest LNG
 
was brought back
into production.
Together with SSE Thermal, Equinor acquired
Triton
Power
 
in the UK. Its key asset, the
 
Saltend power
station
, is planned to be converted to run on
hydrogen in the future.
July
 
To broaden our energy offering in the US, we acquired
the US battery storage developer
 
East Point Energy
LLC.
In Brazil,
Peregrino
 
resumed production after having
suspended operations since 2020.
 
Together with our partners on the Troll and Oseberg
August
Northern Lights
, a joint venture owned by Equinor, Shell and
TotalEnergies, signed the world’s first commercial agreement on
cross-border CO
2
transportation and storage.
September
Equinor celebrated its
50th anniversary,
and
two books about the
company’s history were published.
Completed Equinor’s exit from Russia joint ventures
, after our
withdrawal from the Kharyaga project.
October
In Brazil,
Peregrino phase 2
 
with the new platform C came on
stream, which will extend the field life and reduce CO
2
 
emissions
per barrel.
A final investment decision was made on Equinor’s first battery
project, with the
Blandford battery storage
 
project in the UK.
 
November
We acquired the Danish solar developer
BeGreen
, in another step
towards becoming a market-driven power producer.
Power production started at
Hywind Tampen
, the world’s largest
floating wind farm, which delivered the first power to the Gullfaks A
platform in the North Sea.
The PDO was submitted for Irpa, a field in the Norwegian Sea,
which prolongs the life of the
Aasta Hansteen
field and enables us
to provide more gas to Europe.
 
We postponed submittal of a PDO for the
Wisting
 
project until
2026, based on an overall assessment including the impact of
global supply chain bottlenecks.
December
Equinor secured a ~2 GW lease in the Morro Bay area of California
for commercial-scale floating offshore wind energy development.
Along with Aker BP, we submitted the PDO for the unmanned
Krafla
 
(now
Munin
) platform, around 35km south of the Oseberg
oil field in the central North Sea.
We also submitted the PDO for
Verdande
, a subsea development
that secures important oil volumes for the Norne production vessel
in the Norwegian sea.
Production started from
Johan Sverdrup phase 2
, which will
increase plateau production from the entire field to 755,000 barrels
per day.
 
Production resumed at the
Njord
 
field following an upgrade project
that will extend its lifespan by 20 years.
PDO was submitted for
Snøhvit Future
, a project to maintain high
gas exports from Hammerfest LNG beyond 2030 and reduce
emissions from production.
Equinor in 2022
12
 
Equinor, Annual Report on Form 20-F 2022
 
fields, we began work on the
Trollvind concept
 
– a
1GW floating windfarm to provide energy for the
offshore fields via an onshore connection.
exhibit154p13i0
Equinor, Annual Report on Form 20-F 2022
 
13
Equinor’s Energy transition plan
Progress on our Energy transition plan in 2022
 
Equinor is making progress on the Energy transition
 
plan that was launched in May 2022. We moved in
 
a positive direction across each of the
three main dimensions of the plan: reduction
 
in our operated emissions; allocation of
 
capex share to investments in renewables
 
and low-
carbon solutions (gross capex*); and reduction in
 
the carbon intensity of energy we provide. We also
 
took steps to operationalise our
commitment to a just and inclusive transition, and
 
to implement our biodiversity position.
 
Reduction in our operated emissions
Our ambition is to reduce emissions from our own
 
operations by net 50% by 2030 compared
 
to 2015 levels.
 
We aim for at least 90% of this ambition to be
 
realised by absolute reductions. In 2022, we
 
made significant progress towards this ambition.
Our total scope 1 and 2 operated greenhouse
 
gas (GHG) emissions for 2022 were 11.4 million tonnes CO
2
e, compared to 12.1 million tonnes
CO
2
e in 2021. In total, our operated emissions are
 
now 31% lower than in 2015, the baseline
 
year.
We continued our industry leading performance on CO
2
 
intensity and methane. Equinor’s upstream
 
CO
2
intensity was 6.9kg CO
2
/boe in 2022.
This is an improvement from 7.0kg CO
2
/boe in 2021, well below the target of 8.0kg CO
2
/boe in 2025, and on track towards the ambition
 
of 6kg
CO
2
/boe in 2030. The average methane intensity of our
 
operated assets in 2022 remained unchanged
 
from the 2021 level at 0.02% - around
one tenth of the OGCI (Oil and Gas Climate
 
Initiative) industry average of 0.2%.
 
Capex share to transition investments
 
Equinor’s ambition is to allocate more than
 
50% of our annual gross capex* to renewables
 
and low carbon solutions by 2030 and more
 
than
30% in 2025. In 2022 we invested 14% of our
 
gross capex* into these areas, which is an increase
 
of 3% compared to 2021.
Progress towards net zero
Our ambition is to reduce the net carbon
 
intensity (NCI) of the energy we provide by
 
20% by 2030. This ambition includes scope 3 emissions
from the use of our products. In 2022, we
 
saw a slight decrease in NCI due to two factors:
 
an increase in the ratio of gas to oil in our
production portfolio as well as a slight decrease
 
in overall oil and gas production. The NCI
 
of the energy we provided in 2022 was 66.5g
CO
2
e/MJ, which is 1% lower than in 2021 and
 
a 2% decrease relative to the 2019 baseline
 
year. The 2% reduction in NCI from the 2019
baseline is in line with expectations. As deployment
 
of renewable and CCS accelerates in the
 
coming years, we expect to see greater
progress in NCI reductions, with the majority of
 
progress towards the 20% reduction ambition by
 
2030 expected in the second half of this
decade. Lower overall oil and gas production resulted
 
in a year-on-year decrease in absolute scope 3
 
emissions from 249 million tonnes in
2021 to 243 million tonnes in 2022.
 
The changed energy security situation in Europe
 
has resulted in both positive and negative
 
drivers for Equinor’s energy transition. Increased
demand for oil and, particularly, natural gas has highlighted the need
 
for continued production of and investment in hydrocarbons,
 
while
increased policy support for renewables and low-carbon
 
solutions are likely to accelerate their deployment
 
in both Europe and the US.
Equinor’s ability to deliver on its transition
 
ambitions and its net 2050 ambition will continue
 
to be dependent on enabling policy and regulatory
frameworks.
exhibit154p14i0
14
 
Equinor, Annual Report on Form 20-F 2022
 
Just transition for people and net-positive impact
 
for nature
We recognise that a successful energy transition must
 
take into account its impact on people and
 
nature. In 2022, we launched our Just
transition approach, which lays out five foundational
 
principles to enable us to have a positive
 
impact on the societies in which we operate,
including: respect for human rights; transparency
 
in our financial reporting and advocacy; preparing
 
our workforce for the future; enabling
sustainable supply chains; and bringing resilience to local
 
communities. Examples of how we work
 
to promote a just energy transition in
practice can be found on equinor.com. In addition, we continued to implement
 
our biodiversity position, going beyond the do-no-harm
 
principle
to contributing to net-positive impact, and to promote
 
and engage on biodiversity and nature
 
across internal and external initiatives.
2022 status and performance
Oil and gas
Equinor’s oil and gas production was 2,039
 
thousand barrels of oil equivalent per day
 
(mboe/d) in 2022, a marginal decrease compared to
2,079 mboe/d in 2021. The main drivers of our
 
6% reduction in operated scope 1 and
 
2 emissions were a combination of operational
 
and
portfolio measures including: divestment of our Kalundborg
 
refinery and Bakken asset; modifications and
 
emissions reduction initiatives at our
onshore plants at Mongstad and Kårstø; and a
 
change in strategy at several of our NCS assets
 
from gas injection to gas exports to maximise
supplies to Europe.
 
While the resumption of production from the
 
Peregrino asset added emissions to our operated portfolio
 
in 2022 relative to 2021, the
implementation of a gas import solution for
 
Peregrino in September 2022 will halve the
 
upstream carbon intensity of the asset and avoid
around 100,000 tonnes of CO
2
 
emissions per year. Meanwhile, Hywind Tampen, the world’s first floating wind farm to supply power to offshore
oil and gas platforms, represents an innovative
 
step forward, and is set to reduce CO
2
 
emissions by 200,000 tonnes a year when
 
the project is
fully operational in 2023.
 
In 2022, Equinor also submitted development plans
 
for several large abatement projects, including
 
Snøhvit Future, which is intended to
electrify the Hammerfest LNG facility and provide
 
electric
 
compressors for the Snøhvit gas and condensate field,
 
delivering an estimated CO
2
reduction of 850,000 tonnes per year; and Njord
 
A electrification, which will result in a reduction
 
of 130,000 tonnes per year. As outlined in our
Energy transition plan, rapid reductions in operated
 
emissions from oil and gas in Norway depend
 
on the availability of, and access to, low-
carbon electricity supplies as well as enabling permitting
 
and fiscal regimes.
 
Renewables
 
In 2022, Equinor’s installed renewable capacity
 
was 0.6 GW (equity share) and renewable
 
energy production was 1,649 GWh, an increase
 
on
both metrics compared to 0.5 GW and 1,562 GWh
 
in 2021. We saw the first foundations being laid at
 
the Dogger Bank offshore wind farm in
the UK and completed the Stępień solar project in
 
Poland. In addition, Equinor was selected as
 
a provisional winner of a lease area on
 
the
California Pacific outer continental shelf, one of
 
the world’s most attractive growth regions for offshore
 
wind; and we acquired BeGreen, a
Danish solar developer with a strong project pipeline.
 
Low carbon solutions
Equinor, Annual Report on Form 20-F 2022
 
15
In 2022, Equinor stored 0.5 million tonnes of CO
2
, increased from 0.3 million tonnes in 2021.
 
Accumulated, Equinor has stored 26.3 million
tonnes of CO
2
 
since 1996.
For our low-carbon solutions business, 2022 was a
 
year of continued progress in developing the
 
value chains that will enable hydrogen and
carbon capture and storage (CCS) to be key enablers
 
in the transition. We announced the world’s first commercial
 
agreement on cross-border
CO
2
transportation and storage between the Northern Lights
 
partnership and the fertiliser company Yara. We were also awarded new
operatorship for the Smeaheia CO
2
 
storage site in Norway; CO
2
 
storage licences in the UK; and continued UK
 
government support for our
pioneering H2H Saltend low-carbon hydrogen project.
 
 
16
 
Equinor, Annual Report on Form 20-F 2022
 
About
 
Equinor
 
and
 
our
 
strategy
1.1
1.2
1.3
1.4
1.5
1.6
1.7
1.8
1.9
1.10
This is Equinor
Our history
Our business
Equinor’s market perspective
Equinor’s strategy
Capital and liquidity management
Sustainability at Equinor
Governance and risk management
Our people – To
 
get there. Together
External relations
 
Equinor, Annual Report on Form 20-F 2022
 
17
1.1 This is Equinor
 
We are an international energy company headquartered in Norway, with 22,000 employees in around 30 countries. Our
purpose
 
is to
turn natural resources into energy for people, and progress for society
. Our
values
 
-
open, courageous, collaborative and
caring
 
- guide our decisions and how we engage with each other, our partners, and the societies in which we operate.
 
We are the largest supplier of energy to Europe, a world-leading offshore operator, the largest oil and gas operator in Norway, and an
international pioneer in renewables and low-carbon solutions. Today, in an increasingly unpredictable world,
 
our deliveries of oil, gas
and wind power provide a vital and stabilising contribution to Europe’s energy security, both in the short and long term.
We support the United Nations' (UN) sustainable development goals (SDGs) and the importance
 
of contributing to resolving the
world’s energy trilemma of security, affordability,
 
and climate change. We support the Paris agreement and aim to become a net-zero
company by 2050. We combine industrial strength with innovative thinking, expertise, and collaboration, enabling us to
 
play a
meaningful role in the global energy transition.
Our Energy transition plan was approved by the annual general meeting (AGM) in May 2022. It charts our
 
course towards achieving
our net zero ambition through short-term actions and medium-term ambitions, showing that we have the
 
strategy, ambition,
capabilities, and track record to achieve them.
 
We are publishing our first integrated annual report, combining financial and sustainability (ESG) reporting. The AGM
 
also endorsed
an amendment to our object-clause to reflect our direction as a broad energy company.
 
Alongside our net zero ambition, we will remain a reliable energy supplier and ensure long-term value
 
creation for our shareholders.
We have access to key suppliers, markets, systems, technology, and policymakers. For decades, we have played a unique role in
shaping energy systems across Europe through partnerships with governments, society, and businesses.
 
Our
vision
 
-
shaping the future of energy
 
- sets a clear direction. Future energy systems must differ substantially from current
systems, and the energy industry has the expertise and resources to change them.
Our oil and gas production emissions are already among the lowest in the industry. By 2030, our ambition is to reduce CO
2
 
emissions
from our own oil and gas operations by 50% from the reference year 2015, as well
 
as allocate more than 50% of annual gross
investments* to renewables and low-carbon solutions.
 
To transform the energy system, we must make substantial investments—and quickly—in new solutions. We have defined four key
areas in which we are well qualified to succeed and set clear ambitions:
●
 
Oil and gas: Decarbonise and maintain value creation
●
 
Offshore wind: Industrialise and upscale
●
 
Carbon capture and storage (CCS): Industrialise and commercialise
●
 
Hydrogen: Scale up production and develop new value chains
There are clear synergies between our expertise from existing onshore operations and a future CCS and hydrogen
 
portfolio. A leading
role in Northern Lights, Norway Energy Hub, Clean Hydrogen to Europe (CHE), H2H (Hydrogen
 
to Humber) Saltend, Hywind Tampen
and Snøhvit future demonstrates the extent of our engagement.
Even in the most optimistic future scenarios for the energy transition, the world will remain dependent
 
on oil and gas for energy and
petrochemicals for decades to come. Therefore, it is important that the hydrocarbon resources produced
 
are produced with the lowest
carbon footprint possible.
 
In the years ahead, we will develop new value chains with suppliers, customers and authorities. We believe that industrial
 
scale,
innovation and technology development hold the key to the energy transition. However, the scale of the task means that achieving it
will depend on the foresight and wisdom of leaders, policymakers, science and industry combined.
 
18
 
Equinor, Annual Report on Form 20-F 2022
 
1.2
 
Our History
2007 - 2017
Equinor’s ability to fully realise the potential of the NCS and grow internationally was
strengthened through the merger with Norsk Hydro's oil and gas division on
 
1 October 2007. Equinor’s business grew as a result of substantial investments
 
on the
NCS and internationally. Equinor delivered the world’s longest multiphase pipelines on
the
Ormen Lange
 
and
Snøhvit
 
gas fields, and the giant Ormen Lange development
project was completed in 2007.
By 2007, Equinor had expanded into Algeria, Angola, Azerbaijan, Brazil, Nigeria, UK,
and the US Gulf of Mexico, amongst others.
2017 - 2019
Statoil ASA changed its name to Equinor ASA, following approval of the name change
by the company’s annual general meeting on 15 May 2018. The name supports the
company’s strategy and development as a broad energy company in addition to
reflecting Equinor’s evolution and identity as a company for the
 
generations to come.
The
Johan Sverdrup
 
field came on stream in October 2019. It is powered by
electricity from shore, making it one of the most carbon-efficient fields worldwide.
2020 - 2021
Equinor sets an ambition be a leading company in the energy transition and to become
a net-zero company by 2050,
 
including emissions from production to final energy
consumption.
Equinor announced changes to the reporting segments, corporate structure and the
corporate executive committee (CEC) to further strengthen its ability to deliver on the
 
always safe, high value, low-carbon strategy. The changes will support improved value
creation from Equinor’s world-class oil and gas portfolio, accelerated profitable growth
within renewables and the development of low-carbon solutions.
In January 2021, civil works began at the
Northern Lights
 
development for carbon
transport and storage. In June 2021, the final investment decision was made for the
first phase of the development of the
Bacalhau
 
field. The
Martin Linge
 
field was
brought on stream in June 2021, driven by electric power from shore. The third phase
of the
Troll
 
field development came on stream in August 2021, producing from the
Troll West gas cap. The electrification of
Troll West
is underway. In November 2021,
the decision was made to develop the third phase of the
Dogger Bank
 
offshore
windfarm. To meet growing demand, Equinor
scaled up gas production
 
from the
NCS in 2021.
18 September 1972
 
Equinor, formerly Statoil, was formed by
a decision of the Norwegian parliament
and incorporated as a limited liability
company under the name Den norske
stats oljeselskap AS. At the time owned
100% by the Norwegian State, Equinor's
initial role was to be the government's
commercial instrument in the
development of the oil and gas industry
in Norway. Growing in parallel with the
Norwegian oil and gas industry,
Equinor’s operations were primarily
focused on exploration, development and
production of oil and gas on the
Norwegian continental shelf (NCS).
1979 – 1981
The
Statfjord
field was discovered in the
North Sea and commenced production.
In 1981 Equinor,
 
then called Statoil, was
the first Norwegian company to be given
operatorship of a field, at
Gullfaks
 
in the
North Sea.
1980s and 1990s
Equinor grew substantially through the
development of the NCS (Statfjord,
Gullfaks,
 
Oseberg, Troll
and others). In
the 1990s, Equinor started to grow
internationally, becoming a major player
in the European gas market by entering
into large sales contracts for the
development and operation of gas
transport systems and terminals. During
these decades, Equinor was also
involved in manufacturing and marketing
in Scandinavia and established a
comprehensive network of service
stations. This line of business was fully
divested in 2012.
2001
Equinor was listed on the Oslo and New
York stock exchanges and became a
public limited company under the name
Statoil ASA, now Equinor ASA, with a
67% majority stake owned by the
Norwegian State.
exhibit154p19i0
Equinor, Annual Report on Form 20-F 2022
 
19
exhibit154p20i0
20
 
Equinor, Annual Report on Form 20-F 2022
 
1.3 Our Business
 
A broad energy company
 
We are an international energy company committed to long-term value creation in a low-carbon future. Our
 
portfolio of projects
encompasses oil and gas, renewables, hydrogen and low-carbon solutions, with an ambition of becoming a net-zero
 
energy company
by 2050.
Where we are
Oil and gas
Equinor produces around two million barrels of oil equivalent daily and is responsible for about 70%
 
of Norwegian oil and gas
production. In 2022, Equinor’s activity outside Norway accounted for around one-third
 
of the company’s total oil and gas production,
and this is expected to increase. The Peregrino field in Brazil and the Mariner field
 
in the UK are our largest operatorships outside
Norway.
Refining, processing and marketing
Our refinery, processing plants and terminals transform crude oil and natural gas into everyday commodities such as petrol, diesel,
heating oil and consumer-ready natural gas.
Transportation and marketing, and trading of our products maximise value creation. Most
of our products are exported from Norway to continental Europe, but we also export to
 
the UK, North America and Asia.
Equinor also markets and sells the Norwegian State’s share of natural gas and crude produced on the NCS.
Renewable energy
Equinor provides more than one million European homes with renewable power from offshore wind farms in the
 
UK and Germany. We
develop some of the world's largest offshore wind farms in Europe and the US and are in the process of
 
building a solar portfolio
through partnerships in energy farms in Argentina and Brazil and wholly owned subsidiaries in Denmark
 
and Poland. By 2030, we aim
to have grown our installed renewables capacity (equity-based) from 2022’s 0.6 GW to 12-16 GW and produce 35-60 TWh
 
annually.
Carbon capture and storage
Equinor is pursuing new business models to make carbon capture and storage (CCS) viable. We have 25 years of operational
experience from CCS, and more than 15 years of experience from technology development within large-scale
 
hydrogen value chains
including transport and CCS. Together with our joint venture partners we are developing the Northern Lights infrastructure for
transportation and storage of CO
2
. The project is part of the Norwegian government’s project for full-scale carbon capture,
transportation and storage in Norway.
 
Equinor, Annual Report on Form 20-F 2022
 
21
Technology development
Equinor’s strong ability to develop and apply new technologies and digital solutions constitutes
 
a competitive advantage. Digital
technology is a key enabler for us to develop into a leading company in the energy transition. Our
 
ambition is to allocate 40% of our
research and development capital towards renewables and low-carbon solutions by 2025.
Equinor’s competitive position
We are an energy pioneer with a focused strategy built on our offshore experience and technology leadership. Equinor’s
 
history and
experience building the oil and gas industry in Norway from the 1970s still represent some of
 
the most distinct competitive advantages
for the company 50 years later. As an offshore pioneer and technology developer in Norway, with examples such as piped gas
infrastructure network that started with Statpipe and revolutionary subsea technology development such
 
as the world’s first subsea
gas compression plant on the Åsgard template.
The experience and learnings from industrial and technological developments in Norway and the
 
NCS have been a catalyst for our
assets and operations outside of Norway to ensure safer, more valuable, and lower emissions internationally. In addition to the
industrial and technology DNA originating from the 1970s, we create value as an early mover and
 
industry shaper. Examples such as
CCS at the Sleipner field from the 1990s and testing the floating offshore wind concept in the Hywind demo in
 
the late 2000s have
contributed to our latest technology developments of Northern Lights and Hywind Tampen.
 
 
exhibit154p22i1 exhibit154p22i5 exhibit154p22i4 exhibit154p22i3 exhibit154p22i2 exhibit154p22i0
22
 
Equinor, Annual Report on Form 20-F 2022
 
How we are organised
Equinor’s assets and operations are organised through the following business areas:
Exploration & Production Norway (EPN)
 
explores for and extracts crude oil, natural gas and natural gas liquids in
the North, Norwegian and Barents Seas. EPN aims to ensure safe and efficient operations and transform the NCS
to deliver value for many decades. EPN is shaping the future of the NCS with
 
a digital transformation and solutions
to achieve a lower carbon footprint and high recovery rates.
Exploration & Production International (EPI)
 
manages Equinor’s worldwide upstream activities in all countries
outside Norway. EPI operates across five continents, covering offshore and onshore exploration and extraction of
crude oil, natural gas and natural gas liquids, and implements rigorous safety standards, technological
 
innovations
and environmental protection. EPI intends to build and grow a competitive international portfolio,
 
including through
partner-operated activities.
Marketing, Midstream. & Processing (MMP)
 
works to maximise value creation in Equinor’s global midstream
 
and
downstream positions. MMP is responsible for the global marketing and trading of crude, petroleum
 
products,
natural gas,
 
electric power and green certificates, including marketing of the Norwegian State’s natural gas and
crude resources on the NCS. MMP is responsible for onshore plants and transportation in addition
 
to the
development of value chains to ensure flow assurance for Equinor’s upstream production
 
and to maximise value
creation. Low-carbon solutions, such as carbon capture and storage and other low-carbon energy solutions,
 
are
also a part of MMP’s responsibility.
Renewables (REN)
 
reflects Equinor’s long-term goal to complement its oil and gas portfolio with
 
profitable
renewable energy. REN aims to acheive this by continuing to combine Equinor’s oil and gas competence, project
delivery capacities and ability to integrate technological solutions. REN is currently responsible for wind
 
farms, solar
as well as other forms of renewable energy and energy storage.
Projects, Drilling & Procurement (PDP)
 
is responsible for oil and gas field development and well delivery,
development of wind power, CCS and hydrogen projects,
and procurement in Equinor.
 
PDP aims to deliver safe,
secure and efficient project development and well construction, founded on world-class project execution and
technology excellence. PDP utilises innovative technologies, digital solutions and carbon-efficient concepts to
shape a competitive project portfolio at the forefront of the energy industry transformation. Value is being created
together with suppliers through a simplified and standardised fit-for-purpose approach.
Technology,
 
Digital & Innovation (TDI)
is responsible for research and technology development within Equinor to
further support the business. This includes identifying potential new businesses and value chains
 
for Equinor.
 
Equinor, Annual Report on Form 20-F 2022
 
23
1.4 Equinor’s market perspective
Market overview
At the start of 2022, the global economy remained dampened by Covid-19, and energy markets
 
were already tight when Russia’s
invasion of Ukraine impacted heavily on global energy systems and Europe’s security situation. The cessation of importing
 
energy
from Russia to Europe and an increased focus on energy security and affordability resulted in Equinor becoming the
 
largest gas
supplier to Europe in 2022.
Although the Russian and Ukrainian economies were small in a world context, they played an influential
 
role in energy and commodity
markets. Many European economies relied upon Russian energy and trade links, and rising
 
prices suppressed economic activity,
despite support schemes. The US economy was more sheltered from the fallout but is increasingly
 
impacted by elevated inflation,
rising interest rates and weaker global demand. The zero-Covid policy in China persisted for most
 
of the year, hampering recovery in
domestic activity.
As we enter 2023, the world economy is teetering on the brink of recession, with several regions
 
facing periods of negative growth
1
. A
cost of living crisis is materialising as higher energy prices and inflation are met by further
 
fiscal tightening and higher interest rates.
The outlook still has downside risks, including a potential worsening of the European security situation,
 
a deepening energy crisis, a
failure to curb inflation, and uncertainty over Chinese growth.
Oil prices
The key oil price marker for Europe, dated Brent crude, began 2022 at just below 80 USD/bbl, rising
 
towards 100 USD/bbl in a tight
market before the invasion of Ukraine and peaking at 137 USD/bbl on 8 March, as several countries
 
and companies introduced
voluntary cuts on purchases of Russian crude oil.
When the member countries of the International Energy Agency (IEA) agreed to release
 
strategic supplies in storage, and the US
followed suit, prices fell to around 100 USD/bbl. However, US and EU bans on Russian oil products led to a new price hike,
 
with oil
reaching almost 133 USD/bbl on 14 June.
Prices subsequently declined slowly, reaching a low of 77 USD/bbl in early December due to fears of lower industrial activity caused
by gas shortages, inflation and higher interest rates. Market players weighed the risk that
 
oil demand would fall below even the
constrained oil supply, a discussion still ongoing at year-end since the results of fiscal measures may only be seen in Q1 2023. The
price drop was also driven by paper market effects, as higher price volatility led to higher margin
 
calls. Notably, sanctions on Russian
exports of refined products led to exceptionally high refinery margins, so our standard margin for
 
an upgraded refinery in Europe
averaged 21.2 USD/bbl for 2022, compared to 4.6 USD/bbl in 2021
.
Natural gas prices and European electricity and CO
2
 
prices
Gas prices – Europe
European natural gas prices rose by around 135% year-on-year in 2022, having reached an all-time high of around
 
90 USD/MMBtu in
August, with Russian flows curtailed by roughly 75 Bcm year-on-year. LNG imports played a major role in replacing lost Russian
 
flows,
increasing by almost 70% year-on-year. Security of supply measures regained focus, with countries working to bring new LNG import
capacity online and filling storage capacity ahead of the winter season. Additional pipeline
 
supplies were seen from Norway and
Azerbaijan. High prices and mild weather in the fourth quarter of 2022 resulted in
 
sharp declines in residential and industrial demand.
The European Commission also proposed a series of emergency interventions during the year
 
to limit the effect of high energy prices,
such as windfall taxes, joint gas purchases, and a market correction mechanism to cap Dutch
 
TTF hub prices.
Gas prices – North America
The Henry Hub spot price averaged 6.4 USD/MMBtu for the year, a jump from the 3.9 USD/MMBtu average in 2021. Strong domestic
demand and LNG export outpaced production growth for the year. Producers continued to prioritise capital discipline rather than
unchecked production growth.
Gas rig activity levels finally returned to pre-pandemic levels in the second half of 2022,
 
and meaningful
production growth started to materialise towards year-end.
On the demand side, record heat waves across the country supported high
power demand throughout the summer. US LNG exports grew by ~15% year-on-year, from 110 to 127 bcm, despite the Freeport LNG
terminal being offline for half a year. Extremely high international gas prices drove terminal utilisation up and exports to record highs.
Global LNG prices
Global LNG spot prices were highly volatile in 2022, with the Asian LNG price ranging from
 
18.9 USD/mmBtu to 84.8 USD/mmBtu.
The average Asian LNG spot price increased from 18.4 USD/mmBtu in 2021 to 34 USD/mmBtu
 
in 2022, driven by a surge in LNG
demand in Europe. Europe suffered from congestion at LNG regasification terminals and pipeline infrastructure connecting
 
end
markets, limiting the inflow of gas to high-demand areas, such as Germany. This resulted in large price differentials between LNG
1
Growth in 2022 was 3.1% year-on-year,
 
projected to be 2.4% in 2023. GDP growth rates are from
 
IMF World Economic January 2023.
24
 
Equinor, Annual Report on Form 20-F 2022
 
delivered to Northwestern Europe and the Dutch TTF hub price, which reached a record
 
29.6 USD/mmBtu in early October. These
bottlenecks eased going into 2023, with several floating LNG terminals swiftly deployed on the
 
continent and enhancements made to
pipeline infrastructure. Gas demand declined in Asia due to high LNG prices and additionally
 
in China due to Covid-19 lockdowns,
which released LNG volumes for Europe.
European electric power and CO
2
 
prices
Power prices in major West European markets (the UK, France, Germany, Belgium, Netherlands, Spain, and Italy) averaged 245
EUR/MWh in 2022, up 117% year-on-year. Although 2022 was expected to be a welcome end to the pandemic with an uptick in
production and demand, the
European security situation overshadowed everything.
Power price volatility was extreme, and European
governments intervened in regional markets to combat ever-rising prices.
Whilst the EU ETS (CO
2
) allowance price in 2021 saw a steady rise, the 2022 price was more volatile due to the introduction
 
of
emergency legislation in the energy market and uncertainty surrounding the Fit for 55-package and
 
RePowerEU. Nevertheless, the
price maintained a growth trend, with an average price of EUR 81/tCO
2
 
and a record high of EUR 98/tCO
2
 
in August. Going forward,
we expect the EU ETS allowance price to be driven by a persistent gas-to-coal switch
 
due to a tight gas market and RePowerEU.
After European power and natural gas prices reached an all-time high in August 2022, the EU
 
agreed temporary, but extendable
market intervention measures including a mandatory reduction in power consumption during peak
 
hours and a 10% target for overall
power demand reduction. Also agreed was an inframarginal revenue cap for power generators as well
 
as a solidary fiscal contribution
from the oil, gas, coal and refinery sectors with activities within the territory of the Union. Various industrial actors are pursuing legal
challenges to these decisions. Regarding natural gas a temporary dynamic cap mechanism applicable
 
to the TTF and extendable to
other trading places if proposed by the European Commission was agreed. The EU
 
Agency for the Cooperation of Energy Regulators
(ACER) and the European Securities and Markets Authority (ESMA) have in a recent report
 
concluded that no significant impacts
(positive or negative) on prices can be unequivocally and directly attributed to the adoption of this
 
mechanism. However, both
regulators indicate that this situation could change if prices rise and the prospect of the cap being triggered
 
comes into view. The
European Commission has also initiated the preparation of a targeted electricity market reform and this proposal
 
is expected for medio
March 2023. Member States remain split both in terms of the scope and timing of such
 
a reform effort.
Equinor, Annual Report on Form 20-F 2022
 
25
1.5 Equinor’s strategy
2022 has been both a complex and an extraordinary year for the oil and gas industry due to
 
the Russian invasion of Ukraine and its
consequences for energy security in Europe, weakened economic growth, and inflation, but also with higher
 
than ever profits
experienced by the energy industry. In this context, our strategic beliefs stand firm with climate change being a key challenge. The
world’s energy systems are in transition to meet this challenge.
As Equinor transforms, we work towards striking the right balance between supporting our core, generating
 
cash flow to enable the
energy transition, growing business in new energy areas, and continuing as an attractive investment
 
for our shareholders.
A leading company in the energy transition
By 2030, we aim to be a leading provider of renewable energy and low-carbon solutions, alongside
 
our continued optimised oil and
gas portfolio. We aim to continue being Norway’s energy major and emerge as a leading energy player in select international
 
markets.
We have developed a comprehensive Energy transition plan to become a net-zero company by 2050, including emissions from
production and final consumption.
 
In 2030, our ambition is to have reduced the net carbon intensity by 20%,
 
and by 40% in 2035. We
aim to achieve this reduction by directing more than 50% of our annual gross investments in 2030 towards
 
renewables and low-
carbon solutions while continuing our efforts to reduce our emissions from the production of oil and gas.
Over the next ten years, we aim to generate a substantial cash flow from oil and gas,
 
as our operations on the NCS are expected to
continue delivering positive cash flow at low prices, short payback times, leading breakevens and top quartile
 
production cost, and
among the lowest carbon intensity per barrel of oil. Internationally, the oil and gas portfolio will contribute significantly to after-tax cash
flow as high-value development projects come onstream from the mid-2020s. The cash flow will be used
 
to add to our portfolio, invest
in our transition,
 
and create value for shareholders and society.
We aim to accelerate growth in offshore wind from a strong industrial position to being among the top global players. We are also
positioning for success in low-carbon solutions developing industrial value chains in CCS and
 
hydrogen, and aiming for CCS
leadership in Europe.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
26
 
Equinor, Annual Report on Form 20-F 2022
 
Overall strategic framework
Our Strategic Beliefs
Creating
 
value through
the energy transition
Net-zero ambition gives new industry
opportunities
Technology excellence
 
and
innovation define winners
Market dynamics set margins under
pressure
Our Strategy
Optimised Oil & Gas Portfolio
- capitalising on an
 
advantaged portfolio as a strong
 
cash engine to
fund decarbonisation and transition activities.
We expect our
 
oil and
 
gas portfolio
 
to continue
 
to provide
 
strong free
cash
 
flow in the
 
coming years
 
based on our
 
current price
assumptions.Reducing emissions from
 
operations
 
will remain
 
a top
priority. We will
 
pursue activities
 
where we have the
 
competence,
experience, scale, and
 
an overall competitive
 
advantage to secure
 
a
leadership position. This
 
will be on
 
the NCS and
 
in
 
select
international areas where
 
we can add
 
value by combining
 
use of
existing infrastructure, improving oil recovery, executing
 
strict
production
 
cost
 
control thereby
 
achieving faster
 
return on
investments.
Equinor is divesting lower performing or non-strategic
 
assets.
Improving
 
efficiency will remain a priority, driven
 
by
implementation of technology at
 
scale, digitalisation and
automation. When we access new acreage and
 
future
exploration, we will focus on areas where we already have activity
and existing infrastructure, ensuring shorter time span from
discovery to
 
production to capitalise on previous
 
investments.
Frontier exploration will
 
be limited.
High Value Growth in Renewables
- accelerated deployment to
 
establish a strong
 
industrial position for
value-driven growth.
Equinor aims to be among the top global players in offshore
 
wind,
with
 
12-16 gigawatts of installed renewables capacity by
 
2030.
Focusing on
 
a high value
 
growth in renewables both
 
onshore and
offshore, Equinor’s
 
renewable portfolio will also contribute to
significant value creation.
Equinor is building a profitable renewables business, looking
 
to increase
returns through regional synergies, project financing, strategic
 
farm
downs, and inorganic growth. We seek to execute projects at scale,
strive
 
for technical improvements, and
 
drive profits from
 
energy trading.
Equinor
 
has a position of advantage in floating offshore wind and seeks
to reduce
 
costs through industrial scale projects like Hywind Tampen.
Through early
 
access to less mature markets, where both the risk
 
and
the potential
 
returns are higher, Equinor can
 
build leadership positions.
Equinor is
 
continuously seeking business opportunities in select
renewable markets
 
onshore.
New Market Opportunities in Low Carbon Solutions
- becoming a leader in carbon management and hydrogen.
Low carbon value chains will be critical to decarbonise the
 
global
economy. Equinor is uniquely
 
positioned to become a leader in CCS
and
 
hydrogen in Europe. Equinor is actively contributing to maturing
these
 
markets and aims to achieve a leadership position in
 
the
European CCS
 
market with a
 
market share above
 
25%. We expect
government subsidies
 
to play a key role over the next decade with
policy choices supporting
 
the industry in developing markets for
CCS and hydrogen. Equinor has a
 
strong starting point on the NCS
and in the UK. The company draws on
 
25 years of operational
experience from CCS at Sleipner and Snøhvit
 
and decades of
commercial partnerships with key industrial customers in
Europe. Equinor is already
 
a participant in leading projects
 
to
industrialise
 
CCS and hydrogen like Northern Lights, Smeheia license
and hydrogen
 
clusters in the UK. Equinor is prepared to scale up
investments and
 
technologies as markets mature.
Our strategic pillars and material topics
Always Safe
Safe and secure operations
 
Protecting nature
 
Tackling inequality
High Value
Efficient and predictable operations
Profitable portfolio
Value creation for society
 
Integrity and anti corruption
Low Carbon
Net zero pathway
 
Emission reduction
Governance and People
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
exhibit154p27i0
Equinor, Annual Report on Form 20-F 2022
 
27
Our strategic pillars stand firm
Always safe, High value, Low carbon will continue to guide our business
High value also
means providing
value to the
societies in which
we operate, by
optimising local
employment and
procurement,
contributing with
taxes and
maintaining high
ethical, non-
corrupt practices.
Material
 
topics
Our purpose is to
 
turn natural resources into energy for people and
progress for society. This requires an understanding of the interplay between our business activities and the societies and ecosystems
in which we operate. The figure on the right summarises Equinor's 2022 material topics according
 
to our strategic pillars, and the
rational for their selection.
Always Safe
Safety is our top priority and the core of our
licence to operate. To us, this means safety for
our people, the environment and the societies in
which we operate. We work hard to reduce risk
and avoid incidents and injuries, both among our
own employees and those of our suppliers. We
shall respect human rights and support diversity,
equality and inclusiveness in all our operations.
Low carbon
Our long-term ambition is to become a net zero
company by 2050. This ambition is supported by
our Energy transition plan and is backed by
actions such as: Reducing emissions from our oil
and gas operations, increasing renewables
capacity, establishing value chains in CCS and
hydrogen, increasing the share of non-
combusted products from hydrocarbons, and
using high-quality carbon sinks. In the longer
term, a decline in oil and gas production will also
drive reductions in net carbon intensity towards
net zero in 2050.
High Value
Competitive performance and efficiency
improvements will remain a priority. Our portfolio
is resilient to low prices, has fast return on
investments and world-class breakevens. We are
growing cash flow from its international portfolio,
making it more robust towards lower prices.
Through our leading positions in the offshore
wind market and low-carbon solutions, we are
building a pipeline of future projects within
offshore and onshore renewables, CCS and
hydrogen. We are utilising our trading and
midstream capabilities to optimise the portfolio of
commodities that we provide to our customers,
together with new products and services from
low-carbon solutions.
 
 
 
 
 
 
exhibit154p28i2
 
 
 
 
 
 
exhibit154p28i1
 
 
 
 
 
exhibit154p28i0
28
 
Equinor, Annual Report on Form 20-F 2022
 
We have identified nine topics that we believe are key to deliver on our strategy. In line with the concept of double materiality, these
are topics that may significantly affect our financial or operational performance, or that may significantly impact
 
societies and
ecosystems in which we operate.
Safe and secure operations:
 
Ensure the health, safety and security of people, environment and assets.
As an international
operator of exploration, project development, oil and gas production, refineries, gas plants, solar and wind
 
farms, Equinor faces a range
of potential safety and security risks.
Protecting nature:
Preventing the loss of biodiversity and enhancing the diversity and
 
resilience of ecosystems in which
Equinor operates.
Being present in around 30 countries, Equinor’s operating activities onshore
 
and offshore have actual or potential
impacts on nature.
Tackling inequality:
Respecting and protecting human rights in Equinor’s own activities and supply
 
chain. Creating a diverse
and inclusive workplace with equal opportunities and human capital development, and where
 
discrimination is not tolerated in
any form.
Equinor employs a large and diverse workforce, with operations and supply
 
chains in geographies with a high risk of human
rights violations.
Efficient and predictable operations:
 
Optimisation and management of operations, turnarounds, and technological innovation
.
Equinor’s core business activity is energy provision for society, which relies on optimal operational performance. This is especially
important in the current economic climate with tight energy supply and high demand.
Profitable portfolio:
 
Portfolio development and composition to ensure ongoing profitability with
 
risk assessment and
management of current asset base
.
 
Equinor operates a large global portfolio of assets across several energy resources. The
composition and development of this portfolio influence our ability to ensure continued profitable business
 
activity and long-term value to
shareholders.
Value creation for society:
Generating revenue, job opportunities and economic well-being through local employment,
procurement and taxes
.
Delivering value to society at large and to our host communities, in particular, is fundamental to the success
of our ongoing business activities and the energy transition.
Integrity and anti-corruption:
 
Preventing corruption and ensuring ethical business culture across the company.
Equinor is a
global company with a large number of business relationships and is present in parts of the world where
 
corruption is a high risk.
Net zero pathway
:
 
Achieving net-zero greenhouse gas emissions by 2050, including emissions from
 
the use of our products.
Equinor believes that a net zero pathway creates new business opportunities and is aligned with
 
our purpose of delivering energy to
people and progress for society.
Emission reductions:
Reducing GHG emissions from own production and the use of our products.
Equinor has
significant GHG emissions, and reducing emissions within this decade is urgent to be aligned with the Paris agreement.
Equinor, Annual Report on Form 20-F 2022
 
29
Research and development
Technology and innovation are enablers to deliver on our strategy. Building on a strong technology legacy,
 
we leverage technology
development and implementation of innovative solutions to enhance value and create opportunities
 
for current and future assets.
We continuously evolve our technology direction to capitalise on external innovation and internal capabilities, thereby
 
transforming
through technology, and to:
-
Deliver technology impact to the business today
-
Scale technologies to build the company of tomorrow
-
Transform into a data-driven company
Engagement with technology builds upon a set of principles that emphasizes on embedding data
 
and digital into activities, scaling for
competitive advantage, integrating different technologies to gain from synergies, developing distinct capabilities, strategic
 
partnership
between business lines and technology teams and co-innovating with industry partners. We leverage different tools such as in-house
research and development activities, cooperation with academia, research institutions and suppliers,
 
venturing in startups and
scaleups and open innovation challenges.
30
 
Equinor, Annual Report on Form 20-F 2022
 
1.6 Capital and liquidity management
Capital distribution
Equinor is ambitious to grow the annual cash dividend in line with long-term underlying earnings, in addition to buying back
shares.
When deciding the interim dividends and recommending the total annual dividend level, the BoD take into consideration a
range of factors, including the macro environment, expected cash flow, capital expenditure plans, financing requirements and
appropriate financial flexibility. Dividends are declared in USD. For further details on Equinor’s dividend policy see section 5.1.
As part of our distribution of capital to shareholders, Equinor also buys back shares. The purpose of the share buy-
back programme is to reduce the issued share capital of the company. All shares repurchased as part of the programme are
cancelled. According to a separate agreement between Equinor and the Norwegian State, a proportionate share of the
Norwegian State’s shares will be redeemed and annulled at the annual general meeting, ensuring that the State’s ownership
interest in Equinor remains unchanged at 67%. Execution of share buy-backs after the 2023 annual general meeting is subject
to a renewed authorisation, including renewal of the agreement with the Norwegian State. Share buy-backs will be executed
within applicable safe harbour provisions.
During the year we have increased our cash dividend from USD 0.20 ordinary dividend per share and USD 0.20 extraordinary
dividend per share in the first quarter. The extraordinary dividend increased to USD 0.50 per share in the second quarter and
to USD 0.70 per share in the third quarter.
 
For the fourth quarter of the year, the board proposes to the AGM an ordinary cash
dividend of USD 0.30 per share, and an extraordinary quarterly dividend of USD 0.60 per share.
 
For 2022, Equinor initiated a USD 5,000 million share buy-back programme which was increased to USD 6,000 million later in
the year. The 2022 share buy-back programme started with the first tranche in February 2022 and ended with the fourth
tranche, which was completed in January 2023. The Norwegian State share related to the second, third and fourth tranches of
the 2022 share buy-back programme and the first tranche of the 2023 share buy-back programme, amounting to USD 4,020
million, will be redeemed in 2023. Redemption is subject to approval in the annual general meeting in May 2023.
Debt and credit rating
Equinor generally seeks to establish financing at the corporate (top company) level. Loans or equity are then extended to
subsidiaries to fund their capital requirements. Project financing may be used in cases involving incorporated joint ventures
with other companies. The aim is to always have access to a variety of funding sources across different markets and
instruments, as well as maintain relationships with a core group of international banks that provide a wide range of banking
services.
Our credit rating target is within the single A category on a stand-alone basis. This rating ensures access to relevant capital
markets at favourable terms and conditions.
 
The Group's borrowing needs are usually covered through the issuance of short-, medium- and long-term securities, including
utilisation of a US Commercial Paper Programme (programme limit USD 5.0 billion) and issuances under a Shelf Registration
Statement filed with the SEC in the US and a Euro Medium-Term Note (EMTN) Programme (programme limit EUR 20 billion)
listed on the London Stock Exchange. In addition, Equinor has a multicurrency revolving credit facility of USD 6 billion,
including a USD 3 billion swing line (same day value) option. The credit facility is used as a backstop for the group’s US
Commercial Paper Programme and has a sustainability linked financing element included in the loan agreement related to
Equinor’s CO2 upstream intensity target. Equinor believes that given its current liquidity reserves, including the committed
revolving credit facility of USD 6 billion and its access to global capital markets, Equinor will have sufficient funds available to
meet its liquidity and working capital requirements.
Equinor did not issue any new bonds in 2022 and 2021. The redemption profile of previously issued bonds by currency
denomination is shown below. This includes bonds issued in the US and European bond markets. All the bonds are
unconditionally guaranteed by Equinor Energy AS. The long-term debt portfolio is partially swapped to floating USD interest
rate.
Equinor manages its interest rate exposure on its bond debt based on risk and reward considerations from an enterprise
risk management perspective. This means that the fixed / floating mix on interest rate exposure may vary from time to time.
After the effect of currency swaps, the major part of Equinor’s borrowings is in USD.
 
exhibit154p31i0
Equinor, Annual Report on Form 20-F 2022
 
31
The management of financial assets and liabilities takes into consideration funding sources, the maturity profile of long-term
debt, interest rate risk, currency risk and available liquid assets. In addition, interest rate derivatives, primarily interest rate
swaps, are used to manage the interest rate risk of the long-term debt portfolio.
As of 31 December 2022, Equinor had a long-term credit rating of Aa2 (Moody’s Investors Service) and AA- (Standard &
Poor’s Global Ratings), including an uplift due to state ownership (two notches from Moody’s Investors Service and one notch
from Standard & Poor’s Global Ratings compared to their respective stand-alone credit rating assessments of Equinor). This
rating is well above our rating target and ensures sufficient predictability when it comes to funding access at attractive terms
and conditions.
Liquidity management
Equinor diversifies its cash investments across a range of financial instruments and counterparties to avoid concentrating risk
in any one type of investment or any single country. As of 31 December 2022, approximately 25% of Equinor’s liquid assets
were held in USD-denominated assets, 26% in NOK, 36% in EUR, 7% in SEK, 3% in DKK and 3% in GBP before the effect of
currency swaps and forward contracts. Approximately 31% of Equinor’s liquid assets were held in time deposits, 37% in
treasury bills and commercial papers, 11% in corporate bonds, 7% in money market funds and 0% in current accounts. As of
31 December 2022, approximately 14% of Equinor’s liquid assets were classified as restricted cash (including collateral
deposits).
32
 
Equinor, Annual Report on Form 20-F 2022
 
1.7 Sustainability at Equinor
 
To be sustainable, the energy transition as well as being economically viable requires simultaneously providing energy with lower
emissions whilst also addressing the unprecedented loss of nature and biodiversity and the
 
need for a just, inclusive, and transparent
transition. The interconnectivity and inter-dependency between these issues further require governments,
 
civil society, and private
sector entities such as Equinor to adopt integrated and holistic approaches. The way Equinor responds
 
to these challenges is
fundamental to our strategy and delivering on our purpose.
 
In 2022, Equinor made a strategic decision to further integrate sustainability priorities into the
 
strategy and management of the
company. We defined nine financial, operational, and sustainability-related topics that are critical to achieving our strategy; and we set
ambitions for each topic to measure and report our progress to the board and our stakeholders in a
 
coherent way (see chapter 2 for
further details). From a sustainability perspective, Equinor has three overarching priorities: (i) Net zero by
 
2050; (ii) Evolving from a ‘do
no harm’ principle to a nature-positive contribution; and (iii) Ensuring a just transition.
 
Good governance and transparency are key
enablers.
At both a strategic and operational level, we seek to embed these priorities into relevant governance, risk
 
management and
assurance, and decision-making processes. Alongside addressing these priorities in our own operations
 
and projects, we seek to
influence our partners and increasingly recognise the importance of understanding and managing
 
these issues throughout our supply
chain. We further recognise that external dialogue and collaboration are key to understanding and ensuring
 
a relevant and long-lasting
contribution.
 
The effectiveness of our sustainability management approach is regularly evaluated through performance reviews
 
at several levels,
including the board of directors (BoD), the BoD’s safety, sustainability and ethics committee (SSEC),
 
the corporate executive
committee (CEC), and by corporate functions and business areas. Internal and external audits, verifications
 
and self-assessments
constitute key assurance elements of our management approach. We conduct internal and external benchmarking
 
and participate in
external performance ratings for the same purpose.
” Equinor aims to support sustainable development through
contributing to the energy transition whilst also addressing
biodiversity loss and the need for a just transition.”
Anders Opedal,
CEO of Equinor.
Equinor supports the UN SDGs and shares the view that business has a key role to play in
 
delivering on and contributing to the goals.
Equinor supports all the 17 SDGs and contributes especially to the following six goals: quality education,
 
affordable and clean energy,
decent work and economic growth, climate action, life below water,
 
and partnerships for the goals.
Our sustainability reporting is prepared in accordance with the Global Reporting Initiative (GRI) Standards
 
(2021). The information
provided is also aligned with the World Economic Forum Stakeholder Capitalism reporting metrics. The report,
 
along with its
referenced information, forms Equinor’s Communication on Progress (CoP) to the
 
United Nations Global Compact (UNGC).
 
In alignment with industry practice and regulatory requirements, we report safety and environmental
 
data under our operational control
(100% basis), including operations where Equinor is a technical service provider. Greenhouse gas (GHG) emissions data is reported
on both an equity and operational control basis. Economic data is reported on an equity share basis,
 
and workforce data covers
employees in our direct employment. Human rights data is collected from operated and non-operated
 
assets. Our transparency act
disclosures can be found at equinor.com/reports (ESG reporting centre). For more information about reporting boundaries, see section
5.6 Additional sustainability information. For additional data supporting the report, please refer to
 
Equinor’s sustainability data hub at
equinor.com.
Relevant sections in Chapter 2 provide further specific information on our sustainability-related
 
material topics, management approach
and performance in 2022
.
Further information on the independent assurance for these topics is provided in sections
 
5.6 Additional
sustainability information and 5.7 Statements on this report, including independent auditor reports.
exhibit154p33i0
Equinor, Annual Report on Form 20-F 2022
 
33
1.8 Governance and risk management
Corporate governance
Corporate governance guides the work of Equinor’s governing bodies, our management
 
teams, and individuals, and it safeguards the
shareholders’ and other stakeholders’ long-term trust in the company. Our corporate governance framework and processes are
formed to promote transparency and accountability in decision-making and day-to-day operations.
 
As a public limited company with shares listed in Oslo and New York, Equinor adheres to relevant regulations and applicable
corporate governance codes, including the Norwegian Code of Practice for Corporate Governance
 
(the Code of Practice). Further
details on Equinor’s compliance or explanations of possible deviations with this Code
 
of Practice can be found in section 5.1, Board
statement on corporate governance.
Governing bodies
The board of directors (BoD) focuses on maintaining a high standard of corporate governance.
 
Good corporate governance is a
prerequisite for a sound and sustainable company, and our corporate governance is based on openness and equal treatment of
shareholders. Governing structures and controls help to ensure that we run our business in a
 
justifiable and profitable manner for the
benefit of employees, shareholders, partners, customers and society.
The BoD has the overriding responsibility for supervising Equinor’s management
 
and operations and establishing control systems.
The work of the BoD is based on its rules of procedures and applicable legislation describing its
 
responsibility, duties and
administrative procedures. It has three sub-committees that act as preparatory bodies:
●
The audit committee
 
(BAC) assists in the exercise of the BoD’s control responsibilities in connection with risk management,
internal control and financial reporting.
●
The safety, sustainability,
 
and ethics committee
 
(SSEC) assist the BoD in reviewing the practices and performance of the
company regarding safety, security, ethics, sustainability and climate.
 
●
The compensation and executive development committee
 
(BCC) assists the BoD in matters relating to management
compensation and leadership development, hereunder terms and conditions of employment for the CEO,
 
and on the principles
and strategy for compensation of leading executives in Equinor.
Equinor’s corporate assembly consists of 18 members, 12 which are nominated by the
 
nomination committee and elected by the
general meeting. They represent a broad cross-section of the company’s shareholders and stakeholders. Six members
 
and three
observers are elected by and among our employees in Equinor ASA or a subsidiary in Norway. One of the main duties of the
corporate assembly is to elect the company’s BoD. Further details on the governing bodies in Equinor is
 
set out in section 5.1 Board
statement on corporate governance.
34
 
Equinor, Annual Report on Form 20-F 2022
 
 
exhibit154p35i0
Equinor, Annual Report on Form 20-F 2022
 
35
Board of directors
Equinor’s board consists of 11 members.
The board members have experience from oil, gas, renewables, shipping, telecom, Norwegian defence forces and
environmental and sustainability work. The work of the board is set out in
section 5.1 Board statement on corporate governance.
2
2
 
Resigned from his position as member of the board
 
of directors in Equinor ASA with effect as of
 
16 March 2023.
exhibit154p36i0
36
 
Equinor, Annual Report on Form 20-F 2022
 
Corporate executive committee
The president and chief executive officer (CEO) has the overall responsibility for day-to-day operations in Equinor. The CEO also
appoints the corporate executive committee (CEC), which considers proposals for strategy, goals, financial statements, as well as
important investments prior to submission to the BoD.
Equinor, Annual Report on Form 20-F 2022
 
37
Please see section 5.1 Board statement on corporate governance for a comprehensive
 
account of our corporate governance
framework, functions, and processes with references to The Norwegian Code of Practice for Corporate
 
Governance.
Remuneration of the board of directors
The remuneration of the board of directors is decided by the corporate assembly annually, following a recommendation from the
nomination committee. Remuneration for board members is not linked to performance, and board
 
members do not receive any shares
or similar as part of their remuneration. The board members generally receive an annual fixed
 
fee. Deputy members, who are only
elected for employee-elected board members, receive remuneration per meeting attended. The employee-elected members
 
of the
board receive the same remuneration as the shareholder-elected members.
Remuneration of the corporate executive committee
The board of directors is responsible for preparing and implementing a remuneration policy for the
 
members of the CEC. The policy is
effective for a period of four years, subject to any proposed material changes by the board of directors requiring
 
adoption by the
annual general meeting before the four-year term concludes.
The policy shall contribute to attracting and retaining executives and motivate them to drive the success
 
of the company. A key
principle for Equinor’s remuneration policy is moderation. The reward should be competitive,
 
but not market-leading, and aligned with
the markets that the company recruits from, maintaining an overall sustainable cost level. Equinor
 
places a high focus on fostering
alignment between the interests of its executive management and those of its owners and other
 
stakeholders. Variable remuneration
is aimed at driving performance in line with the company’s strategy and securing long-term commitment and retention with
 
the
company. The receipt of variable remuneration depends on individual and company performance and is subject to a holding period
requirement for some elements. Performance-based variable remuneration compensation has been capped in accordance with
 
the
relevant Norwegian state guidelines.
The remuneration policy was approved by the 2021 annual general meeting. A revised policy will
 
be presented for a binding vote at
the general meeting in 2023. The approved policy will be available on Equinor’s
 
website.
Executive remuneration policy
The executive remuneration policy approved by the 2021 annual general meeting, which serves
 
as the basis for the 2022
remuneration report, including information with respect to the board of directors and corporate assembly, can be found in an appendix
to the 2022 remuneration report on equinor.com/reports.
Risk management
Equinor manages risk related to our strategy selection and delivery of our strategic ambitions. The most
 
important enterprise risks and
risk factors are described in section 5.2 Risk factors.
Equinor’s enterprise risk management (ERM) framework is integrated into all Equinor
 
business activities with a focus on creating value
and avoiding incidents. We consider risks related to shorter-term outcomes, as well as more immature or
 
emerging risk issues that
can impact our business ambitions and corporate risk profile. The Equinor BoD oversees
 
the ERM framework and reviews company
performance.
The ERM approach supports risk-informed decisions and optimal solutions through a focus on the
 
following:
 
●
the value impact for Equinor, including upside and downside risk; and
 
●
compliance with Equinor’s requirements, including a strong focus on avoiding HSE, human rights
 
and business integrity
incidents (such as accidents, fraud and corruption).
 
In general, the risk is managed in the business line as an integral part of employee
 
and manager tasks. The business areas and
corporate functions regularly identify and evaluate risk using established procedures, assess the
 
need for risk-adjusting actions, and
review overall risk management performance. Some risks, such as oil and natural gas price risks and
 
interest and currency risks, are
managed at the corporate level to provide optimal solutions. A corporate risk perspective is also applied
 
in strategy development,
portfolio prioritisation processes, and capital structure discussions.
 
Equinor’s corporate risk team analyses the corporate risk profile
and maintains the ERM overview. Throughout the year, the CEO and the BoD maintain oversight of the risk management framework,
processes, top enterprise risks and the overall risk picture. Areas of particular risk oversight
 
currently include IT and cyber-security,
progress on net-zero, low-carbon value proposition, political and regulatory frameworks, human rights,
 
and capacity and capability
constraints.
Equinor’s risk management process is based on ISO 31000 risk management and
 
seeks to ensure that risks are identified, analysed,
evaluated, and appropriately managed. A standardised process across Equinor supports consistency
 
in risk discussions and
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
38
 
Equinor, Annual Report on Form 20-F 2022
 
efficiency in decisions. Risk is integrated into the company’s management information system (IT tool), where it is linked with
Equinor’s purpose, vision and strategy and associated strategic objectives and KPIs. This
 
tool is used to capture risks, follow up risk-
adjusting actions and related assurance activities, and supports a risk-based approach in the context
 
of a three lines-of-control model
(https://www.equinorbook.com/brandcenter/en/equinorbook/component/default/82415).
Equinor risk management can be broadly considered across the following enterprise impact areas. More detail
 
on specific themes is
provided in relevant material topics sections of this report.
Strategic and commercial risks:
Equinor needs to navigate uncertainty and manage risk to
remain financially robust through the changing energy
context.
 
Climate-related issues influence many aspects of
our strategy selection and execution. Global, regional and
national political developments can change the operating
environment and economic outcomes. Market conditions
related to supply and demand, technological change,
customer preferences and global economic conditions can
significantly impact company financial performance. Our
ability to deliver value from projects and operations can be
impacted by factors related to partners, contractors, global
supply chains as well as regulatory frameworks. Digital and
cyber threats are constantly evolving and can cause major
disruption across our value chains.
Strategic and commercial risk factors:
●
 
Prices and markets
●
 
International politics and geopolitical change
●
 
Hydrocarbon resource base and low carbon
opportunities
●
 
Digital and cyber security
●
 
Climate change and transition to a lower carbon
economy
●
 
Project delivery and operations
●
 
Joint arrangements and contractors
●
 
Competition and technological innovation
●
 
Ownership and action by the Norwegian State
●
 
Policies and legislation
●
 
Finance
●
 
Trading and commercial supply activities
●
 
Workforce and organisation
●
 
Crisis management, business continuity and
insurance coverage
Strategic and commercial risk management:
Overall, Equinor manages risk through a diversified portfolio, robust financial framework, stress-testing
 
and business
planning, investment, and review processes. The company is exposed to oil and gas market
 
price levels. Corporate
hedges may be entered into to reduce or eliminate the cash flow volatility generated from
 
the price levels risk. Equinor
has an insurance-based approach to this hedging, securing downside protection only while keeping
 
the upside in price
exposure open. For the trading business, derivatives risk is managed through a control
 
framework including Value at Risk
and trader mandates, loss limitation systems and daily monitoring of trading profit and loss.
 
Equinor’s liquidity framework
is based on a forward-looking risk management approach to assure that Equinor’s
 
strategic liquidity reserve will cover
both expected and unexpected cash outflows over the subsequent six months, including a potential
 
crisis event and
significant collateral needs.
Risk factors related to low carbon solutions, climate change and transition to a lower carbon economy, workforce and
organisation, cyber security, actions by the Norwegian State are included within top enterprise risks and have direct
follow-up at executive level. Top enterprise risks are assessed in relation to risk appetite statements and risk tolerances
that represent the company’s willingness to take on risk exposure. Actions to manage exposure are implemented
 
and
assessed based on their effectiveness. Risks are reviewed by both the first line (risk owner) and second line (Corporate
risk) with regards to risk management and followed up by the CEC and BoD.
To support portfolio resilience in multiple energy pathways, we have a financial framework in place addressing climate-
related risks, we stress test our portfolio across different energy scenarios, and assess climate-related physical risks.
Risks relating to policies and regulatory frameworks, international politics and geopolitical change, together with
competition and technological innovation are regularly assessed, monitored and managed to improve
 
outcomes for the
company as part of the Equinor’s risk update.
Risk factors related to projects and operations are managed at many levels, including through quality
 
assurance
processes (competence area reviews, e.g., facilities, safety and security, environment, commercial and country risk)
within the investment phase, quality risk management within the project execution risk phase, and
 
continuous
improvement programs in operations. Crisis management, business continuity and insurance coverage are
 
included in
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
39
the evaluation of actions to reduce the impact of unwanted incidents. Digital security and cybersecurity remain
 
in high
focus through a cybersecurity improvement programme to maintain and strengthen cybersecurity
 
capability and reduce
cyber risk.
 
Safety, security and environment risks:
We undertake business activities globally that give
exposure to a wide range of factors that can impact the
health and safety of people, the integrity of facilities, and
the natural environment. Incidents may include release of
health hazardous substances, fire, explosions, and
environmental contamination. Equinor could also be
subject to hostile acts that cause harm and disrupt
operations.
Safety, security and environment risk factors:
●
 
Security
●
 
Health, safety and environmental factors
Safety, security and environment risk management:
We regularly assess our performance through indicators, reviews and assurance activities and, when needed, instigate
improvements. In the current business context, we have a specific focus on top enterprise
 
risks related to major
accidents, security incidents and human rights breaches, as well as following up on aspects of our pathway
 
to net zero
(under strategic and commercial risks). Mitigation of the major accident risk is through continued focus
 
on our I am Safety
Roadmap and rollout of major accident prevention training across the company. Risk exposure to human rights is
addressed through a specific action plan that prioritises key actions to prevent forced labour
 
in the supply chain and
establish new working requirements for human rights due diligence. The European security
 
situation continues to shape
security risk management activity and we have sought to mitigate state actor threats through work
 
on physical security,
including offshore and onshore facilities and pipelines, to guard against drones, and to further develop the management
of cybersecurity.
 
Compliance and Control Risks:
Breaches of laws, regulations or guidelines and ethical
misconduct can lead to public or regulatory responses that
affect our reputation, operating results, shareholder value
and continued licence to operate. Failure to control risks
related to trading processes and transactions can result in
direct losses and potentially affect Equinor’s licence to
trade.
Compliance and Control Risk Factors:
●
 
Business integrity and ethical misconduct
●
 
Supervisions, regulatory reviews and reporting
Compliance and Control Risk Management:
Equinor’s Code of Conduct sets out our commitment and requirements for how we
 
do business at Equinor. We train our
employees on how to apply the Code of Conduct in their daily work and require annual
 
confirmation that all employees
understand and will comply with requirements. We require our suppliers to act in a way that is consistent with
 
our Code of
Conduct and engage with them to help them understand our ethical requirements and how we
 
do business. Equinor
operates a Compliance Program to ensure that anti-bribery and corruption risks are identified, reported, and mitigated,
and have a network of compliance officers who support the business areas globally.
40
 
Equinor, Annual Report on Form 20-F 2022
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
41
1.9 Our People – To
 
get there. Together
How we work
Our success depends on thousands of individuals working together. Each and every one of us makes a difference as we shape the
future of energy.
Equinor’s role as a reliable energy provider is more important than
 
ever, while we also work on securing sustainable energy
production today that will enable the energy transition. This has resulted in a high activity level,
 
and we are proud of all our people
going to great lengths to keep energy production high and secure. In 2022, we strengthened
 
our capabilities in Norway and in
locations around the world, focusing on competence development, recruitment, and our operating
 
model. In Equinor,
 
we have around
22,000 employees globally. We work systematically with diversity and inclusion in our HR processes,
 
from recruitment, talent, and
succession to leadership deployment. In 2022, our gender balance was 31% female, and 21%
 
of our employees were international
(non-Norwegian). During the year we welcomed almost 2,000 new employees to our company. Our focus has been on strengthening
competence development, recruitment, and onboarding while maintaining our people’s well-being and building an inclusive
 
culture
where everyone feels respected, safe, and fully connected to our common goal.
Boundary
Unit
2022
2021
2020
2019
2018
Total number of permanent
 
employees
 
Equinor
group
number
21,936
21,126
21,245
21,412
20,525
Total new hires
Equinor
group
number
1,988
886
774
1,568
905
Developing our people capabilities
In 2022, we implemented further improvements to our workforce planning process to ensure that
 
there is an even stronger link
between our strategy, business plans, and the people capabilities we develop for Equinor. Our workforce planning process involves
leaders and employee representatives in the definition of the competence and capacity needed to deliver on future
 
plans, as well as in
the development of plans to close and mitigate gaps, such as competence development
 
and recruitment.
Building and utilising our collective competence
Our collective competence is a key enabler for Equinor to deliver on current and future
 
ambitions. We are therefore supporting
employees to build future-fit competence and are continuously updating our learning offering. We continuously monitor the uptake of
all formal learning to ensure management focus and further optimise our learning portfolio.
In 2021 we adjusted our operating model to further expand the use of competence centres to
 
accelerate competence development
and flexibility in people allocation across activities and value chains. In 2022, we implemented further
 
improvements to make sure that
our processes and tools are fit for purpose to enable this, including a review of various IT solutions.
Growing our workforce
To support our ambitions for the future, we added almost 2,000 new recruits in 2022 to replenish and grow our workforce. A high
activity level in our existing business, combined with high growth ambitions, and a growing
 
number of retirees, requires an increased
intake of both emerging talent and experienced hires.
Creating a great place to work
In Equinor, we continuously involve our people in the development of the company. This includes
 
internal cross-functional
collaboration and liaising with union representatives and safety delegates according to local
 
law and practice. In 2022, this was vital in
activating our new operating model, flexible work, humanitarian aid related to the war in Ukraine,
 
and an increasingly complicated
security situation. We respect employees’ rights to organise and their opportunity to bring forward their opinions, and we
 
have the
same clear expectation of our suppliers and partners.
 
Every year we conduct a global people survey (GPS) to evaluate and improve key areas
 
that impact safety, working environment,
engagement, and the drive for continuous improvement and change in Equinor. For 2022, the GPS scores show a positive
development in commitment, motivation and HSE compared to 2021, but also some negative
 
developments for some important topics,
such as continuous improvement, rapid implementation of good ideas and further development
 
of our operating model. We are
focused on developing our people, directing their time and effort to prioritised activities in more flexible ways. We continue to
 
adapt to
our new ways of working and our focus on flexibility and collaboration. In Equinor, we have established a set of flexible work principles
that describe the ways we organise our work, use our facilities, and behave together, and 2022 was about implementing and
operationalising these principles.
Performance and reward framework
Our performance and reward framework measures progress and results in a holistic way across two dimensions,
 
both by what we
deliver and how we deliver. Business delivery and behaviour are equally weighted when recognising and rewarding individual
performance. The CEO, his direct reports and Equinor’s broader leadership are assessed
 
based on results within a broad range of
financial, operational and sustainability topics. The annual bonus for employees
 
is based on the same holistic assessment of company
performance. A comprehensive set of performance indicators and monitoring reports are made available to
 
all employees in Equinor’s
management information system. The KPIs are reported on a regular basis from operational levels to the governing
 
bodies to ensure
42
 
Equinor, Annual Report on Form 20-F 2022
 
transparency in risk and performance management – this is how we keep individuals accountable for the
 
development of our
company.
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
43
1.10 External relations
Stakeholder engagement
In line with our values of being open and collaborative, we actively and regularly engage with internal
 
and external stakeholders to
discuss our strategy, approach, and performance. It is important to engage to enrich and challenge our priorities and positions, so that
we can continuously improve our performance and strategic direction.
Throughout 2022, we engaged with numerous stakeholders, including investors, governments, regulators,
 
business partners and
suppliers, customers, local communities, academic institutions, and non-governmental organisations. Equinor
 
strives to have a
systematic approach to engage with a broad set of relevant stakeholders for our business and the
 
communities where we operate.
A tangible example of how we engage with stakeholders was the company’s Energy transition plan. In May
 
2022, Equinor put forward
its Energy transition plan for an advisory vote to shareholders at the annual general meeting (AGM).
 
The plan provides an overview of
how the company is progressing towards its 2050 net-zero ambition through short-term actions and medium-term
 
ambitions. This
provided an opportunity for all investors to actively engage with the company’s ambitions and performance. 97.5% of the
 
votes
representing shareholders present at the AGM were cast in approval of the proposed resolution. In addition to
 
the government as the
largest shareholder, almost three out of four investors voted in favour.
The chair of the BoD, the CEO and senior managers, amongst others, regularly engage in stakeholder
 
dialogues. We consult
stakeholders both directly and indirectly, and we strive to reduce potential language, social and geographical barriers.
Associations and industry initiatives
Equinor participates in a wide range of relevant associations and industry initiatives to engage
 
in dialogue, share knowledge and learn
from others. The following are some of the associations that worked closely with: CCSA, G+ Global
 
offshore wind health and safety
organisation and Global Wind Offshore (GWO),
 
Hydrogen UK, the International Emissions Trading Association (IETA), International
Association of Oil and Gas Producers (IOGP), Ipieca, Methane Guiding Principles, Offshore Norge, Oil and Gas Climate
 
Initiative
(OGCI), Oil and Gas Methane partnership, Renewable UK, Sustainability Hub Norway, the Task Force on Climate-related Financial
Disclosures, the Task Force on Nature related Financial Disclosures, United Nations Global Compact, Wind Europe, and the World
Business Council for Sustainable Development.
Further information on our Climate policy engagement activities can be found in section 2.3 Low carbon.
Working with partners and suppliers
Equinor holds participating interests in many assets operated by other companies. Similarly, other companies hold participating
interests in assets that we operate. The way we work and follow up on partner-operated assets
 
seeks to ensure that governance, risk
and performance management are compatible with our own requirements and practices. Through the applicable
 
committee structures
in the partnerships, we follow up and support the management of risks and performance related to
 
safety, security,
 
ethics, integrity,
and sustainability,
 
including climate, environment, human rights and social performance.
A significant part of our business activities are carried out by suppliers working under
 
contracts awarded by Equinor. We undertake
safety and sustainability qualification of suppliers’ management systems to ensure that our
 
suppliers have an acceptable standard
before entering into a contract. The qualification is based on an audit of suppliers’ management
 
system according to the main
principles of ISO 9001 (quality), 14001 (environment), 27001 (information security) and 45001 (occupational
 
health and safety), in
addition to the United Nations Guiding Principles on Business and Human Rights. We work closely with
 
our suppliers and regularly
verify deliveries to ensure that agreed actions are undertaken.
Integrity due diligence (IDD) is performed to identify integrity concerns and ensure that the required
 
IDD process is complete prior to
establishing a new agreement with a counterparty.
 
 
44
 
Equinor, Annual Report on Form 20-F 2022
 
 
Enterprise
 
level
 
performance
2.1
2.1.1
2.1.2
2.1.3
2.1.4
2.2
2.2.1
2.2.2
2.2.3
2.2.4
2.3
2.3.1
2.3.2
Performance 2022
Always safe
Safe and
 
secure operations
Protecting nature
Tackling inequality
–
Human rights
Tackling inequality
–
Diversity and inclusion
High value
Group analysis
Efficient and predictable
 
operations
Profitable portfolio
Value creation
 
for society
Integrity and anti
-
corruption
Low carbon
Net zero pathway
 
Emissions reduction
Equinor, Annual Report on Form 20-F 2022
 
45
Performance 2022
As a large, international energy company, Equinor impacts and is impacted by a variety of factors. We create value by providing
society with energy – 2,039 mboe per day of oil and gas and a total of 2,653 GWh of
 
electric power in 2022. Through the efficient
operation of our portfolio, we generate profits and shareholder returns. This financial strength, combined
 
with our engineering
expertise, enables us to contribute to the rapid deployment of renewable energy and low-carbon solutions. We also contribute to
socio-economic development through jobs for around 22,000 employees and our 8,000 suppliers and pay
 
a significant amount of tax
in the societies in which we operate.
 
At the same time, our operations generate significant greenhouse gas emissions – in 2022 we
 
emitted 11.4 million tonnes carbon
dioxide equivalent (CO
2
e) from our own operations. We also impact biodiversity and ecosystems through for example discharges
 
to
sea or land, emissions to air, and the use of land and sea areas and natural resources.
In our industry, the exposure to health and
safety risk is high. Risks related to breaking of human rights, integrity and security are also inherent
 
in the activities we and our
suppliers perform. While profitable growth and shareholder value is critical to any business, we must create
 
long-term growth and
lasting value in a sustainable way.
 
In recognition of the complex interplay between our business, nature and society, we use the concept of double materiality to inform
our business decisions. We systematically analyse impacts with two perspectives in mind: the impacts that Equinor
 
has on society and
nature, and the impacts that society and nature have on Equinor. This dual perspective ensures a broader understanding of the
material topics we need to manage in the delivery of our long-term strategy as well as in
 
our day-to-day operations. The identification
and prioritisation of material topics is based on our understanding of relevant risk factors, consultation
 
with internal and external
subject matter experts, independent analyses and our ongoing stakeholder engagement as summarised in chapter
 
1. The chief
executive officer (CEO) and ultimately the board of directors (BoD) are responsible for the approval of the annual report,
 
including the
material topics, monitoring indicators and ambitions.
The material topics are grouped according to our three strategic pillars: Always safe, high value
 
and low carbon. For each of the
material topics, KPIs/monitoring indicators have been identified, and clear ambitions have been set. The table
 
below summarises our
framework and provides a high-level overview of our progress in 2022. Subsequent sections of this chapter
 
detail our ambitions, key
risk factors, management approach, performance data, and evaluation of our progress for each of the
 
nine topics. For each material
topic we include a summary of Equinor’s key impacts to nature and society, as well as through cross referencing relevant corporate
risk factors identified in chapter 1, an assessment of the impact of nature and society to Equinor.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
46
 
Equinor, Annual Report on Form 20-F 2022
 
ALWAYS
 
SAFE
KPI/MONITORING
INDICATOR
2022 AMBITION
(TARGET
YEAR)
STATU
S
PERFORMAN
CE
2022
2021
SAFE AND SECURE OPERATIONS
Serious Incident
Frequency (SIF)
 
(number per million
hours worked)
≤0.4 (2022)
n
0.4
0.4
Total Recordable
Injury Frequency
(TRIF) (number per
million hours worked)
≤2.2 (2022)
n
2.5
2.4
Completion of cyber
security awareness
training for employees –
since commenced June
2021 (%)
95% (2022)
n
97.7
n/r
PROTECTING NATURE
Assets and licences in
and
adjacent to protected
areas (number of)
From 2023: New
projects in
protected areas
or areas of high
biodiversity
value to
establish a plan
aiming to
demonstrate net
positive impact
n
35
19
Serious accidental spills
 
(number of)
0 (2022)
n
0
0
TACKLING INEQUALITY
Determine a suitable
human rights indicator
Pilot a set of
human rights
indicators (2022)
n
Completed
Inclusion index score
(%)
I: ≥80 (2025)
n
77
77
Material topics and 2022 performance
HIGH VALUE
KPI/MONITORING
INDICATOR
2022
AMBITION
(TARGET
YEAR)
STATU
S
PERFORMANC
E
2022
202
1
EFFICIENT AND PREDICTABLE OPERATIONS
Equity production
liquids and gas
(mboe per day)
2022 outlook
guiding ˜2%
above 2021
1,3
n
Growth
0%
(2039)
207
9
Production cost
equity volumes
(USD/boe)
<5 USD/bbl
 
(2021-2026)
1,2
n
5.6
2
5.4
PROFITABLE PORTFOLIO
Return on Average
Capital Employed*
(ROACE) (%)
>14% yearly
 
(2022-2030)
1,4
n
55.2
22.7
Relative Total
Shareholder Return
(Relative TSR)
(quartile)
Above average
in ranking
among
 
peers
1
n
6 of 12
2 of
12
Relative ROACE*
(peer group rank)
First quartile in
ranking among
 
peers
1
n
1 of 12
2 of
12
Organic Capex*
(billion USD)
2022 outlook
 
guiding
 
USD 10
1
n
8.3
5
7.9
VALUE CREATION FOR SOCIETY
Payments to
goverments (billion
USD)
Not applicable
49.2
11.8
Share of
procurement spend
locally (%)
Not applicable
88.7
91.4
INTEGRITY AND ANTI-CORRUPTION
Confirmed corruption
cases (number of)
0 (2022)
n
0
0
Employees who
signed-off the Code
of Conduct (%)
≥95% (2022)
n
95
84
LOW CARBON
KPI/MONITORING
INDICATOR
2022 AMBITION
(TARGET YEAR)
STATU
S
PERFORMANC
E
2022
2021
NET ZERO PATHWAY
Net carbon intensity (gCO
₂
e/MJ)
-20% (2019 -> 2030)
-40% (2019 -> 2035)
n
66.5
67.1
Renewable energy installed capacity
(GW, equity)
12-16 installed (2030)
n
0.6
0.5
Annual gross CAPEX to
renewables and low carbon
solutions* (%)
>30% (2025)
>50% (2030)
n
14
11
EMISSIONS REDUCTIONS
Absolute GHG emissions scope 1
and 2 (million tonnes CO
₂
e)
Net 50% emission
reduction
(2015 -> 2030)
n
11.4
12.1
Upstream CO
₂
 
intensity, Scope 1
(kg CO
₂
/boe)
<8 kg/boe (2025)
<6 kg/boe (2030)
n
6.9
7.0
Text in bold:
Key performance indicator.
 
1
 
Outlook and ambitions presented at CMU 2022 or in Annual report 2021 (forward looking
updated in CMU).
 
2
USD 2021 real base.
 
3
Rebased for portfolio measures.
 
4
Based on 2022 CMU price scenario (65 USD/bbl).
5
Adjusted to USD/NOK exchange rate assumption in the Outlook presented at CMU 2022
n
 
Ambition met in 2022.
 
n
 
Ambition not met in 2022.
 
n
 
Plan in place, on track to reach longer-term ambition.
 
n
 
Plan in place, not on track to reach longer-term ambition.
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
47
Summary of enterprise level material topics for 2022
Always safe
 
Improved safety and security performance
In 2022 there were no fatalities and no actual or potential major accidents, and the total
 
number of actual serious incidents is the
lowest ever recorded. Equinor also recorded the lowest number of serious oil and gas leaks
 
ever, and there was no significant harm to
people, assets or operations due to security incidents. The company, however, experienced too many personal injuries and did not
meet the 2022 target. Although there was a decline in work related illness,
 
the total level of absence has increased further since 2021.
Based on our 2022 performance, we recognise the need to continue to improve our health,
 
safety and security performance. Given
the measures reinforced in 2022, we consider our approach as adequate, and health, safety and
 
security objectives remain a top
priority for Equinor’s management.
Satisfactory performance on most nature related topics
Equinor’s performance related to non-GHG emissions to air and regular discharges to
 
sea, is considered satisfactory. Although
volumes of accidental spills are lower than in 2021, we are not satisfied with the slight increase
 
in number of uncontrolled discharges
and breaches of discharge permits in our operations in Norway, and there is continued focus on improvement activities to address
compliance with relevant environmental regulations. Our approach and ongoing improvement activities
 
related to our impacts on
biodiversity, for example new disclosure metrics and preparation of NPI plans and site-specific inventories of key biodiversity features,
are viewed as representing an adequate response to the need for action against loss of biodiversity.
Further maturation of approach to human rights
 
Equinor has continued to mature its approach to addressing human rights and tackling inequality
 
with two important milestones in
2022 being the articulation of our just transition framework, and stand-alone human rights
 
statement. We continued our efforts to
further integrate human rights practices into the way we work, with a particular focus on addressing
 
indications of forced labour and
unacceptable working conditions in our supply chains.
 
We consider our management approach adequate to address the salient risks
but recognise the need for more systematic efforts and broader collaborations to tackle systemic issues. We will
 
also continue our
efforts to identify meaningful indicators of social and human rights performance with the aim of reporting in
 
a more quantitative fashion
in future years.
Diversity and inclusion performance satisfactory
The focus in 2022 has been on updating our diversity and inclusion (D&I) ambition, strategy
 
and metrics to better support our
business strategy, and reflect our external context, societal expectations and international reporting standards. While diversity targets
have been put on hold in 2022 due to internal reorganisation, we continued to measure
 
our inclusion index and use this data to
identify actions that drive an inclusive
 
culture. The inclusion index performance remains at the same level compared to a three-year
average, and we recognise the opportunities for improvement. The plans for 2023 focus on
 
further operationalising D&I, setting
targets and actions locally and systematically measuring progress on both diversity and inclusion.
High value
 
Efficient and predictable operations
Equinor delivered stable total equity liquids and gas production throughout 2022 while increasing
 
gas production from the NCS in
response to the energy security crisis in Europe. Production came in at 2,039 mboe per day compared
 
to 2,079 mboe per day for
2021 primarily due to portfolio changes including Equinor’s exit from Russia. Divestments
 
and natural decline were offset by the
Snøhvit, Peregrino and Njord fields resuming production and start-up of Johan Sverdrup
 
phase 2 and Peregrino phase 2 in the fourth
quarter of 2022. Total renewables power generation increased by 5.6 % in 2022 to 1,649 GWh, mainly due to the full year production
from the Guanuil IIA solar plant in Argentina.
Through efficient and stable production Equinor delivered a unit production cost for 2022 at 6.1 USD/boe (5.6
 
USD/boe real 2021).
Performance came in above guiding, reflecting the challenging economic environment which
 
developed since setting the target at the
beginning of the year. Increasing energy cost, higher environmental costs and portfolio changes resulted in the higher unit production
cost for 2022.
Profitable portfolio
Equinor’s strong financial performance and results has placed the company in
 
a robust financial position. We delivered first among
peer group on Adjusted Return on Average Capital Employed*
 
for the year with a 55% adjusted ROACE*, and above average on
Relative Total Shareholder Return*.
Equinor’s oil and gas portfolio is well positioned to deliver energy during an
 
ongoing energy crisis. Strong cash generation enables
Equinor to continue reinvestment in an optimised oil and gas portfolio and ensuring high value growth in renewables
 
and low carbon
solutions, with USD 8.3 billion organic capex* (adjusted to USD/NOK exchange rate assumption
 
in the Outlook presented at CMU
2022)
 
in 2022. Equinor continue to optimise and reprioritise the non-sanctioned projects to ensure
 
high value creation though cycles.
Significant societal value creation
Delivering value to society at large and to our host communities in particular, is fundamental to the success of our ongoing business
activities and the energy transition. Our 2022 performance was geared towards ensuring
 
crucial energy production and supply, and
 
 
48
 
Equinor, Annual Report on Form 20-F 2022
 
providing significant tax contributions, employment and procurement spend.
 
In 2022, Equinor paid over USD 45 billion in taxes and
spent around USD 17.1 billion on procurement.
Integrity and anti-corruption targets met
The number of confirmed corruption cases were zero, which is aligned with the target. 95% of employees signed-off the company’s
Code of Conduct which also addressed the gap identified in 2021.
 
Low carbon
Satisfactory progress on climate performance
Equinor’s total scope 1 and 2 GHG emissions were 11.4 million tonnes CO
₂
e in 2022, representing a decrease compared to a three-
year average. The CO
₂
 
intensity was 6.9 kg CO
₂
 
per barrel of oil equivalent, which is less than half of the current global industry
average of 16 kg CO
₂
/boe. Equinor also continued its strong methane intensity performance with 0.02% compared to
 
the OGCI
average of 0.17%. Equinor’s scope 3 GHG emissions (use of sold products) were 243 million
 
tonnes CO
₂
e which is a slight decrease
compared to a three-year average. Equinor expects to maintain the same level of oil and gas
 
production until 2030, which may result
in increased emissions from use of sold products.
The company is on track towards its ambition of allocating 30% of its gross capex* to renewables
 
and low carbon solutions by 2025,
with investments increasing to 14% in 2022, compared with 11% in 2021.
To account for both emissions and energy produced, Equinor uses a net carbon intensity (NCI) methodology, which accounts for
scope 1, 2 and 3 emissions. Equinor’s NCI was 66.5 g CO
₂
e/MJ which is a slight improvement from 67.1 g CO
₂
e/MJ in 2021.
2.1 Always safe
Guided by our values
Safety is Equinor’s top priority and the core of our license to operate. To us, this means safety for our people, the environment, and
the societies in which we operate. Our values
open, courageous, collaborative and caring
guide us in our continuous work to
safeguard people, the environment and assets. We operate in a high-risk industry with regards to both safety and security. As an
international energy company, we are highly dependent on strong collaboration with our contractors, who undertake two thirds of our
activity.
 
Material topics.
 
The
Always safe
 
material topics have a strong link to how Equinor impacts nature and society. Our double materiality evaluation
further highlights that several of our corporate risk factors (crisis management and business continuity, safety and environmental
impact, and security threats) may have a material impact on Equinor.
 
“Safe and secure operations”
 
addresses our commitment to ensure the health, safety and security of our people, and integrity
 
of our
operations. The corporate KPIs Serious Incident Frequency (SIF) and Total Recordable Injury Frequency (TRIF) are the most
important ways we measure our performance in this regard, and SIF is also part of the framework
 
for executive remuneration.
 
“Protecting nature” acknowledges our responsibility for nature in relation to acute spills, regular emissions and
 
discharges, as well as
our presence in or near protected areas.
 
Tackling inequality states that we must be active in handling the inequalities we meet in our business, both internally and when
interacting with suppliers, business partners and society in general. Among our own employees
 
we work systematically to strengthen
diversity and inclusion and reduce our gender pay gap, including the use of quantitative
 
scores and ambitions. Our ambition is that
everyone should have equal opportunities regardless of gender, age, nationality ethnicity, sexual orientation, religion and disability.
 
Through our work with human rights issues, we expand our ownership for safety to the societies
 
in which we operate.
 
 
 
exhibit154p49i1 exhibit154p49i0 exhibit154p49i0 exhibit154p49i0 exhibit154p49i1 exhibit154p49i1
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
49
2.1.1 Safe and secure operations
TOPIC
DESCRIPTION
IMPACTS TO
NATURE
AND SOCIETY
PRINCIPAL RISK
FACTORS/IMPACT
ON EQUINOR
KPI/MONITORING
INDICATOR
AMBITION
AND STATUS
Ensure the health,
safety and security
of people,
environment
and assets.
Equinor’s operating
activities have actual
and potential impacts
on people, environment
and
assets. These include
the potential of injury,
work
related illness and
major accidents.
 
Crisis management,
business continuity and
insurance coverage
 
Digital and cyber security
 
Health, safety and
environmental factors
 
International politics and
geopolitical change
 
Joint arrangements
●
 
and contractors
 
Security
Serious Incident Frequency
(SIF) (number per million
hours worked)
≤0.4 (2022)
n
Total Recordable Injury
Frequency (TRIF) (number
per million hours worked)
≤2.2 (2022)
n
Completion of cyber security
awareness training for
employees - since
commenced
June 2021
95% (2022)
n
n
 
Ambition met in 2022.
 
n
 
Ambition not met in 2022.
 
n
 
Plan in place, on track to reach longer-term ambition.
 
n
 
Plan in place, not on track to reach longer-term
 
ambition.
Text in bold:
Key performance indicator.
 
Contextual introduction
Over the course of 2022, the geopolitical context evolved with the invasion of Ukraine
 
and changes in the related security threats.
Running safe, efficient, and predictable operations remained Equinor’s priority to continue to be
 
a reliable supplier of energy to the
markets in Europe in a highly challenging environment. Equinor collaborated closely with
 
Norwegian authorities to manage the
security situation in 2022 and received support to strengthen physical security both offshore and onshore.
 
Equinor is a broad international energy company and faces a range of potential safety
 
and security risks including well blowouts,
ignited hydrocarbon leaks, structural collapses, oil and gas spills and leaks, crime, occupational incidents,
 
and work-related illness.
Cyber security continued to be a major risk factor throughout 2022.
Two thirds of our activities are undertaken by contractors. We are fully committed to strong collaboration with our contractors to
safeguard people, environment, and assets.
Management approach
Our vision is zero harm, which is supported by our strategic pillar Always safe. We believe that all accidents related to
 
people,
environment and assets can be prevented. To guide us in our journey towards our vision and strategy, we have selected SIF and
TRIF as our key performance indicators. SIF includes major accident hazard and other serious safety accidents
 
and near misses.
Near misses are incidents with no actual consequences but with a serious potential.
On 1 July 2022, the Norwegian Ministry of Petroleum and Energy decided that Equinor ASA
 
would be subject to parts of the
Norwegian Security Act and later notifications stated that Equinor would become subject to activities which
 
are of vital importance to
fundamental national functions. Equinor then began to work on responding to the requirements
 
of the Security Act decision and
achieving compliance.
Management system
 
exhibit154p50i0
50
 
Equinor, Annual Report on Form 20-F 2022
 
Our safety and security management system capitalises on the collective knowledge gained
 
and good practice established over many
years. This is fundamental to ensure safe and efficient execution of activities and clear roles and responsibilities. Based
 
on learning
from incidents, a framework for major accident prevention was developed in 2021. The framework
 
set a structure based on recognised
industry practice for high-risk industries. The framework for major accident prevention relies on leadership,
 
culture and organisational
frame conditions, safe design and practices and safety barriers. Human and organisational performance principles
 
are embedded in
the framework. During 2022, the framework for major accident
 
prevention was implemented globally.
 
exhibit154p51i0
Equinor, Annual Report on Form 20-F 2022
 
51
Safety roadmap
The I am safety roadmap sets the direction for Equinor’s safety improvement. It guides
 
the safety work and outlines prioritised
activities throughout the company across four categories: safety visibility, leadership and behaviour, learning and follow up, and safety
indicators.
Human and organisational performance (HOP) principles underpin the way in which we develop a
 
proactive and visible safety culture.
The HOP approach provides guidance on how people, technology, organisations and processes interact as a system, and how these
conditions can influence the causes of human errors. HOP is implemented in leadership training
 
across the company, and HOP focal
points were established and trained in 2022 to support the roll-out and training.
 
Equinor works together with suppliers and contractors to achieve a standardised and common approach to the
 
safety improvement
agenda. Formalised collaborations based on Life saving rules, Annual wheel and common KPIs
 
have been established and committed
through signed collaboration charters. Joint meetings across the established safety charters were held in
 
2022 and alignment on the
agreed targets and priorities achieved. All these arenas are open and transparent venues for
 
sharing of learning both ways.
 
Close cooperation with other operators is vital for the work to succeed. Equinor engages
 
proactively across industry bodies such as
the International Association of Oil & Gas Producers (IOGP), Oil Companies International Marine
 
Forum (OCIMF) and the G+ Global
Offshore Wind Health & Safety Organisation.
 
Equinor continuously works to improve and develop new leading indicators to proactively guide
 
the safety approach across the
company.
Crisis and continuity management
 
To ensure we are prepared, we work to have appropriate emergency response capabilities in place to limit the consequences of
incidents, should they occur. Our oil spill response capabilities are in line with good international practice and leverage expertise and
resources made available through our membership of local and international oil spill response
 
organisations. Equinor personnel
routinely participate in training and exercises on their roles and responsibilities in emergency response
 
situations, to be sufficiently
prepared if, and when, incidents occur
.
Joint exercises with interaction between internal and external actors were carried out during
2022.
In response to the European security situation, a strategic project team reporting to the CEO and
 
the CEC was established from
February to December to ensure risks and challenges were managed holistically across
 
the company. The purpose was to maintain
safe and efficient operations and prepare the company for short- and long-term impact. The strategic project team
 
facilitated close
interaction and collaboration with key stakeholders, partners and Norwegian authorities and security
 
agencies. Equinor increased the
state of alert in Norway and for parts of the international business in September. We strengthened our personnel security efforts to
exhibit154p52i1 exhibit154p52i0
52
 
Equinor, Annual Report on Form 20-F 2022
 
raise awareness and handle insider risk both for our own employees and in collaboration with suppliers. During
 
the year, Equinor
continued to strengthen cyber security barriers and improved response and recovery capabilities
 
across the company.
 
To safeguard onshore plants and offshore installations, Equinor reviewed its onshore and offshore physical security and improved the
security barriers in line with the Equinor state of alert requirements and guidance from
 
the Norwegian authorities.
Health and working environment
Health and working environment is an integral part of our efforts to safeguard people. We focus on risk management and
 
systematic
monitoring of work-related illness related to factors such as chemicals, noise, ergonomic workplace,
 
and psychosocial aspects. In
addition to monthly reviews of registered cases, we capture information from employees through
 
our Global People Survey (GPS),
which includes questions related to psychosocial and mental health risk factors.
Performance disclosure
Serious incidents
In 2022, we experienced no actual nor potential major accidents, and no fatalities.
Our serious incident frequency (SIF), which includes
 
near misses, ended on target at 0.4 incidents per million work hours. This is an
improvement over the five-year period 2018–2022 from 0.5 to 0.4. The number of actual incidents
 
has halved in the same period.
Process safety
In 2022 there were 8 serious oil and gas leaks (with a leakage rate ≥ 0.1 kg per second).
 
This is the lowest number of leaks ever
recorded and came close to achieving our ambitious 2022 target of a maximum of seven
 
leaks. No serious well control incident
recorded.
 
There was an increase in Tier 1 process safety incidents that included loss of primary containment. A total of 14 incidents were
classified as Tier 1 in 2022, while the total number for 2021 was 8. However, the sum of Tier 1 and the less severe Tier 2 incidents
was reduced.
The positive trend on the safety-critical maintenance backlog continued
during 2022. Reducing this backlog is important in preventing major
accidents.
exhibit154p53i0
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
53
Personnel health and safety
 
The total recordable injury frequency (TRIF) increased to 2.5, up from 2.4 in 2021 and the 2022 target
 
of 2.2 was not achieved.
 
However, more detailed analysis shows that according to Equinor’s internal severity classification there is a decline in the most
serious injuries.
 
Health and working environment
Indicators
Boundary
Unit
2022
2021
2020
2019
2018
Work related illness
Equinor group
number per year
132
161
161
135
82
Sickness absence
Equinor ASA
employees
percentage of
planned work hours
5,1
4,6
4,2
4,4
4,6
There was a decline in the number of work-related illnesses, with 132 recorded cases
 
in 2022. The total level of absence from
sickness has increased since 2020, to reach 5.1 (as a percentage of planned workhours) in 2022.
Security incidents
 
Security threats are monitored and reported on a frequent basis and risks are managed holistically
 
across the physical, cyber and
personnel domains. Equinor experienced some cyber-related incidents during the year, such as a distributed denial of service (DDoS)
attack on an Equinor server, which had limited impact and was rapidly resolved.
There was increased targeted activism against Equinor’s operations from environmental
 
groups. None of the security incidents led to
any significant harm to people, assets, or operations.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
54
 
Equinor, Annual Report on Form 20-F 2022
 
Security
2022
2021
2020
2019
2018
Percentage of security
personnel who have received
formal training in the
organisation's human rights
policies - South America and
Africa
1
Equinor
group
percentage
100
91
85
n/r
n/r
Security e-learning training for
employees and contractors
Equinor
group
number of
participants
19,580
15,694
n/r
n/r
n/r
Completion of cyber security
awareness training for
employees - since
commencement in June 2021
Equinor
group
percentage
97.7
n/r
n/r
n/r
n/r
1
As signatories of the Voluntary Principles on Security and Human Rights (VPSHR), Equinor does not use armed guards unless
 
it is
strictly necessary. In certain locations the threat is of such a nature that the arming of guards is crucial, while in others is it not
possible to procure security services without the inclusion of firearms.
Performance evaluation
No fatalities and no actual or potential major accidents were recorded in 2022, and the total
 
number of actual serious incidents is the
lowest ever recorded.
 
The total recordable injury frequency (TRIF) is higher when compared to industry benchmarking. In addition,
 
our sickness absence
has increased over the last two years. These areas represent a challenge for us, and
 
we are working to understand the causes and
mitigate risks.
 
Based on our 2022 performance, we recognise the need to continue to improve our safety performance.
 
Given the measures
reinforced in 2022, we consider our approach as adequate to improve our performance and close the
 
gap on our health, safety and
security targets. These objectives remain a top priority for Equinor’s management.
 
exhibit154p49i0 exhibit154p55i1 exhibit154p49i0
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
55
2.1.2 Protecting nature
TOPIC
DESCRIPTION
IMPACTS TO
NATURE
AND SOCIETY
PRINCIPAL RISK
FACTORS/IMPACT
ON EQUINOR
KPI/
MONITORING
INDICATOR
AMBITION
AND STATUS
Preventing the loss of
biodiversity and
enhancing the
diversity and
resilience of
ecosystems in which
Equinor operates.
Equinor’s operating
activities have actual
and potential impacts
on nature. These
include the potential for
serious uncontrolled
discharges, as well as
operations in or near
protected areas.
 
Health, safety and
environmental factors
 
Policies and legislation
 
Supervisions, regulatory
reviews and reporting
Assets and licences
in and adjacent to
protected areas
(number of)
From 2023:
New projects in
protected areas or
areas of high
biodiversity value to
establish a plan aiming
to demonstrate net
positive impact
n
Serious accidental
spills (number of)
0 (2022)
n
n
 
Ambition met in 2022.
 
n
 
Ambition not met in 2022.
 
n
 
Plan in place, on track to reach longer-term ambition.
 
n
 
Plan in place, not on track to reach longer-term
 
ambition.
Text in bold:
Key performance indicator.
 
Contextual introduction
For Equinor, as a large offshore oil and gas operator with a growing offshore wind portfolio, the management of our activities and their
potential impacts on the marine environment continues to be a priority. Historically our operated onshore activities were limited to oil
and gas, including drilling and fracturing of wells in the US. Recent investments in and
 
our ambitions for CCS, solar, hydrogen and
battery storage projects underline the increasing importance of our management of onshore environments.
Our operations have actual or potential impacts on nature through pollution, including regular and
 
uncontrolled discharges to sea or
land and emissions to air. Our use of land and sea areas and related disturbances, including the noise of our operations and the risk
of collisions with animals, and introduction of alien invasive species from maritime vessels, may
 
also negatively impact biodiversity
and ecosystems. This is of particular importance if our activities are in or near protected areas or areas of
 
high biodiversity value.
Through our partners and suppliers, we may also indirectly contribute to impacts on nature, for
 
example in activities where large
quantities of materials like metals, cement and chemicals are used.
There are increasing expectations from policy makers, academia, civil society, and communities among others, for urgent action to
reverse biodiversity loss this decade.
 
Global and regional biodiversity policies and risk management and disclosure frameworks are
being developed and strengthened in support of the Kunming-Montreal Global Biodiversity Framework.
 
These developments
constitute a new set of detailed expectations for companies related to impacts and dependencies on nature
 
and have direct relevance
to Equinor’s operations and its supply chains. Equinor aims to go beyond the
 
zero-harm principle and take relevant actions to reduce
potential adverse impacts and contribute to positive impacts.
The shift to a more resource-efficient, circular economy is a key area increasingly being reflected in stakeholder
 
expectations and
commercial agreements, for example in the context of the EU Taxonomy and for new wind farm developments. Another important
development is the increased focus on the dependencies of nature and ecosystem services. Relevant
 
dependencies for Equinor
include the extraction of natural resources in our supply chain and the bioremediation service that healthy
 
oceans provide when we
discharge produced water containing minor fractions of oil and chemicals to sea at some of our
 
offshore platforms.
Management approach
To manage our impacts on nature, alongside complying with applicable laws and regulations, we aim to apply recognised
environmental management practices. This includes application of the precautionary approach, best available techniques,
 
the
mitigation hierarchy and the ISO 14001 environmental management principles.
In 2021, in support of the global ambition of reversing nature loss by 2030, we announced in
 
our Biodiversity position statement
ambitions of going beyond the ‘do-no-harm’ principle by developing a net-positive approach. In 2022, we
 
finalised the first set of
methodologies for net-positive impact plans and site-specific inventories of key biodiversity features
 
and started establishing such
inventories. From 2023, we will develop plans aiming for a net-positive impact for all new development
 
projects in protected areas or
areas of high biodiversity value. The methodologies were developed through pilots in investment
 
projects (including collaboration with
bp at our joint offshore wind developments off the US East Coast), and assets in operation, and further implementation is
 
planned.
Further information can be found in our sustainability pages at equinor.com.
During 2022, we also followed the work of the Taskforce on Nature-related Financial Disclosures (TNFD) as a member of the TNFD
Forum. To prepare for implementation of emerging nature-related risk and disclosure frameworks, we initiated internal materiality
assessments and assessments of relevant metrics and indicators.
56
 
Equinor, Annual Report on Form 20-F 2022
 
Our governance, risk and performance framework enables us to systematically manage
 
environmental aspects. Our first priority is to
avoid potential negative impacts. If this cannot be done, we aim to minimise them. In
 
the planning phases of all our assets, before
construction or operations can commence, a key part of our management approach is environmental
 
and social risk and impact
assessments, including stakeholder engagement. This also includes baseline studies, surveys, monitoring programmes,
 
and
collaborative research projects to build knowledge and develop tools. Our oil spill response capabilities are
 
described in section 2.1.1
Safe and secure operations. We publish documentation from project-specific impact assessments on our own website and make
biodiversity-related data available through solutions owned by others, such as the Norwegian
 
and UK authorities.
In 2022, we enhanced our focus on environmental regulatory compliance including specific
 
improvement initiatives for our oil and gas
assets in Norway.
 
This included improved governance and collaboration, training and awareness initiatives,
 
increased follow-up, and
operational measures.
Substitution of chemicals for less environmentally harmful ones is part of our continual improvement efforts. For example,
 
in 2022, we
completed a campaign to substitute firefighting foam containing per- and polyfluoroalkyl substances (PFAS) with fluorine-free foams
across our Norwegian operations.
 
We are also piloting an approach for sharing more biodiversity-related data via data.equinor.com. Equinor is a member of the Ocean
Decade Corporate Data Group co-hosted by the Intergovernmental Oceanographic Commission
 
(IOC) of UNESCO and Fugro. The
aim of this initiative is to make privately held ocean data available for scientific research and decision making
 
to address the
challenges identified through the United Nations Decade of Ocean Science for Sustainable Development.
Growth in renewables is core to our Energy transition plan, and we need to understand
 
how best to achieve this ambition in a nature-
positive way. For example, we actively use Hywind Scotland, the world’s first floating wind farm, as a test site to increase our
knowledge of potential environmental impacts of such assets, and we aim to continue this
 
work with the new Hywind Tampen wind
farm on the NCS. Research topics include sound emissions from wind turbines, and we use remote
 
sensing technology to assess
potential reef-effects. We also undertake research on potential impacts on birds and how to mitigate them.
 
Collaboration with external stakeholders is fundamental to our approach, which helps us
 
to build our knowledge and develop
innovative solutions to address biodiversity. In 2022, we extended our participation in a range of research programmes and industry
partnerships, such as the UN Environment Programme World Conservation Monitoring Centre’s (UNEP-WCMC) Proteus Partnership.
We also joined a project led by the International Union for Conservation of Nature (IUCN) which aims to identify
 
good practices for
renewable energy development.
We are also working to improve our understanding of circular economy opportunities. This includes our approach to waste
management in general, as well as to specific recycling opportunities such as wind turbine blades
 
and materials from the
decommissioning and removal of offshore facilities. Through the supply chains for our oil and gas, and
 
renewables activities, we
purchase large quantities of steel, other metals, cement, and various materials used
 
in drilling and completion of wells. Each of the
respective supply chains may impact nature in various ways and have specific waste management
 
needs and practices. We apply the
waste hierarchy to primarily avoid waste generation and follow key circular economy principles such
 
as the re-use, recycling and
recovery of materials. The largest waste volumes from our own operations are oily wastewater
 
from oil and gas processing and oiled
drill cuttings.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
57
Performance disclosure
Non-GHG emissions, discharges and waste
 
Selected environmental performance data for 2022 is shown in the table below. A complete set of performance data can be found in
our Sustainability datahub at equinor.com.
There were no serious accidental spills in 2022, and the total volume of accidental oil spills
 
and other spills was considerably reduced
from 2021 to 2022. However, the total number of spills increased slightly. A discharge of 581,000 m
3
 
of treated process water from the
Mongstad refinery water treatment plant was reported as a breach of permit. This was because the discharge occurred closer
 
to shore
than permitted and the volume was larger and the period longer than initially communicated to the Norwegian
 
Environment Agency.
Over the past four-to-five years, non-GHG emissions to air and regular, permitted discharges of oil in water to sea have trended
downwards slightly, or remained at the same level. The increase in SOx emissions from 2021 to 2022 was mainly due to the restart of
production at the Peregrino FPSO in July 2022. However, SOx emissions from the asset are lower than in earlier years due to an
ongoing fuel switch from diesel to imported natural gas. Hazardous waste quantities increased
 
from 2021, mainly caused by increased
volumes of water dispatched from Mongstad for further treatment. This water stems from
 
well cleaning at offshore platforms.
Increased quantities of drill cuttings due to increased drilling activity in Norway also contributed to
 
an increase in hazardous waste
quantities. Exempt waste quantities are at a low level since only three wells were drilled and
 
fractured during 2022, all of which are at
a single location in the US.
Indicators
Units
2022
2021
2020
2019
2018
SOx emissions
ktonnes
1.1
0.9
1.3
2.2
1.8
NOx emissions
ktonnes
32
34
36
41
42
Non-methane volatile organic compounds
ktonnes
23
26
35
40
46
Accidental oil spills (net volume >0)
Number
m
3
111
120
136
219
239
33
40
154
8,913
138
Other accidental spills (net volume >0)
Number
m
3
122
98
117
204
199
302
3,335
3,997
57
934
Serious accidental spills
Number
0
0
2
3
1
Regular discharges of oil in water to sea
ktonnes
1.1
1.1
1.3
1.2
1.1
Hazardous waste generated
 
ktonnes
304
280
318
313
244
Non-hazardous waste generated
ktonnes
37
33
29
40
31
Exempt waste generated - drill cuttings and solids
from US onshore operations
ktonnes
1.2
0
17
84
55
Exempt waste generated - produced water and
flowback water from US onshore operations
million m
3
0.1
2
5
7
6
Biodiversity and nature
 
In 2022, we expanded the scope of reporting in relation to where we have operations in protected
 
areas and areas of high biodiversity
value.
 
We now include linear infrastructure (e.g., pipelines and cables) for which Equinor is technical service
 
provider on behalf of
other operators, resulting in inclusion of the Europipe I and II pipelines which both crosses the
 
Wadden Sea UNESCO World Heritage
Site (WHS). The
 
Wadden Sea was included in the WHS list in 2009, while the pipeline installations were completed in 1995
 
and 1999,
respectively. We otherwise did not operate within other sites on the WHS list or sites in the International Union of Conservation of
Nature (IUCN) category 1a (“Strict nature reserve”) or category 1b (“Wilderness area”).
The number of assets and licences inside or adjacent to protected areas increased from 19 in
 
2021 to 35 in 2022. This is partially
caused by the increase in renewables activity and the increased disclosure scope (as explained
 
above). A summary of our presence
in relation to protected areas and areas of high biodiversity value is shown below and
 
a complete overview is available in the ESG
reporting centre on equinor.com.
NPI plans are being developed for several assets, for which the Empire Wind project in the US
 
and the Rosebank project in the UK
are first in scope.
exhibit154p58i0
58
 
Equinor, Annual Report on Form 20-F 2022
 
1.
 
“Assets” means offshore platforms including subsea
 
tie-ins, onshore plants, pipelines and other
 
linear infrastructure in operation or under
construction
2.
 
“Licences” includes only those licences
 
where there have been operational activities
 
other than 1) above, e.g.,
 
seismic acquisition,
exploration drilling, site surveys
3.
If several protected areas (PA) or areas of high biodiversity value (AHBV)
 
are present within a proximity category
 
around a given asset or
operation, they are counted as one. If a given
 
PA or AHBV are within proximity categories for several assets
 
or operations, it is counted in for
each of these assets or operations. Subsea
 
installations within a field are included
 
in the counting of the platform it is tied in
 
to. For existing
linear infrastructure like pipelines, service
 
lines and cables, only the ‘Inside’ and ‘Adjacent’
 
categories are applied. In cases where linear
infrastructure is installed during a given reporting
 
year, all proximity categories are applied. Information on geographic
 
location of cases
represented in the table above can be found
 
in the “Sustainability performance data
 
hub” on Equinor.com.
Withdrawal and consumption of freshwater in 2022 was 6 million m³, a reduction from 8 million m³ in
 
2021. We had no oil, gas or
renewable energy production in, nor did we withdraw water from areas of high or extremely high
 
baseline water stress as defined by
the World Resources Institute’s Aqueduct® tool.
Performance evaluation
Non-GHG emissions, discharges and waste
 
For 2022, non-GHG emissions to air and the volume of discharges and spills to sea were mainly at the
 
same level or trending
downwards. We have also taken measures to reduce SOx emissions at the Peregrino FPSO. We therefore believe our approach
 
to
non-GHG emissions is effective and is producing the intended results.
Generated waste volumes,
 
which stay at the same levels as previous years, are mainly dependent on activity levels within
 
drilling, well
clean-up and maintenance. We also initiated an improvement initiative to establish a circular economy framework aiming
 
for better
management of use, reuse and recycling of resources, including waste.
Although the accidental spill volumes are lower in 2022 compared to the previous year, we are not satisfied with the fact that
 
the
number of such spills increased slightly since 2021. As also raised by the Norwegian Environmental
 
Agency, we continue to have
compliance issues related to the number of accidental spills and breaches of discharge permits for our operations
 
in Norway. The
improvement activity addressing governance, competence, awareness and performance in this area, continues.
Biodiversity and nature
 
Our approach and ongoing improvement activities related to our impacts on biodiversity are viewed as representing
 
an adequate
response to the global expectations and need for action against loss of biodiversity. The increase in numbers showing our presence in
or adjacent to protected areas, is the outcome of increased disclosure scope (as explained above) and our
 
expanding renewables
portfolio. We continued our implementation of a net positive approach as outlined in our biodiversity
 
position, including relevant
Equinor, Annual Report on Form 20-F 2022
 
59
disclosure metrics and preparation of NPI plans. The reduced level of withdrawal and consumption
 
of freshwater is considered a
positive development.
 
exhibit154p49i0 exhibit154p49i0 exhibit154p49i0 exhibit154p49i0
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
60
 
Equinor, Annual Report on Form 20-F 2022
 
2.1.3 Tackling
 
inequality – Human rights
TOPIC
DESCRIPTION
IMPACTS TO
NATURE
AND SOCIETY
PRINCIPAL RISK
FACTORS/IMPACT
ON EQUINOR
KPI/
MONITORING
INDICATOR
AMBITION
AND STATUS
Respecting human
rights in Equinor’s
own activities and
supply chain.
Equinor has operations
and supply chains in
geographies where
human and labour rights
may be at risk. With
8,000 direct suppliers,
our activities may
impact a vast number of
people.
 
Business integrity and
ethical misconduct
 
Joint arrangements and
contractors
 
Policies and legislation
 
Workforce and
organisation
Determine a
suitable human
rights indicator
Pilot a set of human
rights indicators (2022)
n
n
 
Ambition met in 2022.
 
n
 
Ambition not met in 2022.
 
n
 
Plan in place, on track to reach longer-term ambition.
 
n
 
Plan in place, not on track to reach longer-term
 
ambition.
Contextual introduction
Within a turbulent global landscape, ethical and transparent behaviour is a critical foundation for
 
business when considering how to
tackle inequality. The Russia-Ukraine war and its ripple effects on access to food and energy, alongside the cost of living crisis, can
have significant implications for individuals who already face challenges to their basic human rights.
 
Understanding and managing the
risk of adverse human rights impacts related to our activities is at the core of our human
 
rights commitment. This is consistent with the
United Nations Guiding Principles on Business and Human Rights (UNGPs), the ten principles
 
of the Global Compact and the
Voluntary Principles on Security and Human Rights. We recognise that our activities can cause, contribute, or be linked to negative
human rights and other social impacts, especially in jurisdictions with weak regulatory frameworks or enforcement,
 
and where our
activities face inherent risks. Addressing gaps towards international labour standards continues to be our main
 
salient issue.
Specifically, addressing the possibility of forced labour connected to our supply chains, a situation exacerbated by global instability,
increased inequality and continued effects of the Covid-19 pandemic, remains our key concern.
Management approach
Equinor’s human rights policy applies to all our activities. In accordance with the company’s risk management
 
system, we identify
adverse human rights risks and impacts, and work to prevent, mitigate or remediate as relevant to
 
each situation. During 2022, we
continued our efforts to further integrate human rights practices into the way we work, supported by regular senior leadership
engagement.
 
Focus on labour rights and living wages is identified as one of the core priorities of the Just
 
Transition plan which embeds respect for
human rights as fundamental to achieving a just and fair transition.
The executive-level human rights steering committee continues to serve as an advisory group focusing
 
on learning and experience
transfer, actions to address Equinor’s key human rights risks, and supporting the engagement with and reporting to the CEC
 
and BoD.
Areas of discussion have included risk mitigation in project development, enterprise risk level and
 
mitigation, and new disclosure
initiatives to drive transparency.
 
Within Equinor, it is the responsibility of the risk-owner to conclude where human rights due diligence efforts should be prioritised.
Defining such priorities is based on regular risk and portfolio assessments and supported by a corporate team
 
of human rights experts
who help ensure alignment across the portfolio. In 2022, we continued to look for indications of forced
 
labour and unacceptable
working conditions in our supply chains, particularly within fabrication and construction activities across Asia
 
and in core countries
such as Brazil. Compared to previous years, risk assessments in the earlier phases of project planning were
 
prioritised, to better
inform decision making and allow for more effective mitigation. To understand risks related to our activities, we perform environmental
and social impact assessments.
 
These are an essential part of our project development process and allow for proactive consultation
with stakeholders to inform our understanding of community impacts.
 
This includes addressing potential impacts on indigenous
peoples, which continue to be a priority. For certain high-risk activities, we may perform additional and specific human rights risk
assessments, typically supported by external experts. During project execution, by engaging with
 
potentially affected stakeholders
through worker dialogue,
 
we get better understanding of any potential issues and are able to respond with
 
appropriate means of
remediation where necessary. We follow up with suppliers based on identified risk, including verifications, tracking of actions and
ongoing dialogue. We expect all current and future suppliers to be familiar with and apply our general human rights expectations.
 
We
include specific human rights clauses in all our contracts, based on scope and location of delivery, which typically define the risk level.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
61
As we enter 2023, a further strengthening of our management system is underway, including global working requirements for human
rights due diligence and new requirements for internal reporting. We continue to build our expert-level corporate capabilities, both
through the recruitment of specialists and by improving work processes to better leverage internal capacity
 
and know how.
 
The introduction of a standalone Human rights statement is a direct response to the Norwegian
 
Transparency and Human Rights Due
Diligence Act and is an opportunity to broaden our external disclosure and communication on our human
 
rights approach, risks and
work. To ensure compliance with the Act, Equinor has created an internal procedure for capturing and processing information
requests.
 
Performance disclosure
Labour rights and decent work
We require all new suppliers to be screened for social criteria. In line with our approach to performing
 
risk assessments in the early
phases of our projects, we assessed 283 suppliers for social impacts in 2022. From this, 154
 
suppliers were identified as having
significant gaps. 84% of these suppliers have through closing of gaps become qualified, while
 
the rest of the suppliers are yet to
complete their improvement plans. If we find that a supplier will not implement necessary improvements,
 
the supplier will not be
awarded a contract. There were no circumstances where suppliers were not willing to improve to
 
become qualified, and no
circumstances where findings or lack of collaborative actions resulted in a need to terminate
 
a relationship.
Aligned to our corporate priorities, we assessed conditions for workers involved in specific construction projects
 
in Malaysia,
Singapore, Thailand and China. Indicators of forced labour as defined by the International Labour
 
Organization (ILO) were identified in
one contract we are linked to, mainly related to payment of recruitment fees, retention of identity documents,
 
and restriction of
movement
.
This means that during 2022, we identified 61 individuals as subject to at the minimum
 
one indicator of forced labour
within our supply chains. We continued
 
to work with our partners to provide remedy in these instances, including compensation
towards undue payments. In 2022 payments were made to 1,791 previously identified workers,
 
to the value of over USD 2 million.
Labour rights and working conditions in the supply chain
Indicators
Boundary
Unit
2022
2021
2020
2019
2018
Human rights (HR) assessments
of suppliers conducted
Equinor group
number
24
30
37
50
75
Workers interviewed
Equinor group
number
808
974
343
650
1000
Countries in which supplier HR
assessments undertaken
Equinor group
number
11
10
9
16
20
Employees working with our
suppliers trained (class room
course)
Equinor group
number
264
128
190
409
514
exhibit154p62i0
62
 
Equinor, Annual Report on Form 20-F 2022
 
The number of supplier assessments varies with nature and level of activity
and is not necessarily comparable year-on-year. However, our approach to
be more targeted towards high-risk sites and suppliers and focus on site
visits and worker interviews as opposed to more traditional audits, has
resulted in a gradual decrease. We do not find it relevant to set targets
towards number of assessments.
 
Due to publicly reported concerns of serious labour exploitation in solar
supply chains, we continued our task force focusing on actions to mitigate
short-term and longer-term risks. Actions include increasing and requesting
traceability throughout the supply chain, seeking contractual safeguards,
engaging with industry initiatives, and investigating opportunities for
alternative sourcing routes.
A step-up in shipping and oil and gas storage
During 2022, a special task force, consisting of business line
representatives and human rights expertise developed specific
requirements and tools to embed human rights due diligence in our
shipping and oil and gas storage business. Alongside these efforts,
tailormade full-day classroom training was delivered to approximately 70
business professionals.
 
Human rights were also a core topic at our regular Working safely with
suppliers conference. Bringing shipping and storage suppliers together in
Stavanger, this event includes leadership expectations, panel
conversations, and roundtable discussions to explore common challenges
and ways forward.
Supplier dialogue and onsite human rights assessments were performed at
two yards where new-build vessels are being constructed.
Community risks and impacts
 
No potential or actual adverse impacts of indigenous peoples’ rights were identified during 2022. Across
 
our operated assets, Equinor
received no eligible grievances according to our internal procedures. Issues raised which
 
are deemed ineligible include, for example,
requests for donations, sponsorships, jobs, and requests for information about collaborating or partnering with
 
Equinor in various
projects.
 
Together with Shell, we continued to actively manage the remaining human rights risks and impacts associated with the resettlement
of 29 households and the discontinuation of farming and fishing affecting 446 households in the
 
area identified for a potential LNG site
in Lindi, Tanzania. Specifically,
 
the focus has been on ensuring the longer-term sustainability for impacted households. Actions
include the signature of a Land agreement and the development of an agricultural livelihood baseline
 
assessment, as the preparatory
stage for an agricultural livelihood restoration programme to be implemented in 2023.
Through our joint activities to develop a solar park with Scatec in Northern Brazil, we resettled two families
 
who were previously living
and working in a location with no rights to the land or formal work contracts. Through
 
strong Equinor-led stakeholder engagement and
compliance with International Finance Corporation (IFC) standards and our human rights policy, both families have taken legal
ownership of their new property, including land allocation for one family who wanted to continue farming.
Governance and capacity building
In addition to the human rights steering committee, executive leadership engagement in 2022 included participation
 
in several
external, cross-sectoral and multi-stakeholder coalitions including a Commissioner role in the Business
 
Commission to Tackle
Inequality and board member at the WBCSD Energy Pathway Board, with focus on human rights
 
and the just transition. There was
continued engagement with industry leaders, academia and subject matter experts to share experiences
 
and to align on good
practice. Internally, general and specific capability building efforts continued through 2022, focused around new and emerging
regulations, and in particular the Norwegian Transparency Act.
We continued to deliver a third-party-facilitated Human Rights In Practice course for supply chain professionals and company
representatives,
 
focused on labour rights, Ethics, Anti-Corruption and Human Rights.
Information requests according to the Transparency
 
Act
In 2022, Equinor received three information requests, which were all responded to within the legislative
 
deadline. In addition, twelve
questions and requests for action or information were received but not deemed legitimate under the scope
 
of the Transparency Act.
These were treated separately on a case-by-case basis.
Equinor, Annual Report on Form 20-F 2022
 
63
Finally, we continued the active participation in mediations related to a tragic crane accident at a South Korean yard in 2017. The
process is facilitated by the Norwegian OECD National Contact Point, following the filing of a complaint
 
alleging breaches by several
companies, including Equinor, of the OECD Guidelines for Multinational Enterprises.
Performance evaluation
We continue, as do many, to be challenged to find meaningful and objective assessments of performance within the field of business
and human rights. In 2022, as a first step towards maturing a broader performance framework, we
 
piloted a set of internal monitoring
indicators relevant to our key risks. We will continue to build on the learnings from this pilot with the
 
aim of reporting in a more
quantitative fashion in future years.
 
As we continue our risk-based approach to human rights due diligence within our global
 
supply chains, we see significant risks of
adverse human rights impacts, particularly related to decent work and the possibility of forced labour.
 
Whilst it is never satisfactory to identify substandard labour conditions, we see that our efforts to understand potential
 
impacts earlier
in the project and procurement process as a further step towards more risk avoidance and effective mitigation.
 
Our efforts in 2022 focused on furthering specific actions towards the construction sector, including building leverage with peers and
partners, and particular efforts were made towards our midstream business including shipping and
 
oil and gas storage. A further
strengthening of our internal work processes will drive more systematic and documented due
 
diligence across the portfolio.
 
 
exhibit154p49i0 exhibit154p49i0 exhibit154p49i0
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
64
 
Equinor, Annual Report on Form 20-F 2022
 
2.1.4 Tackling
 
inequality – Diversity and inclusion
TOPIC
DESCRIPTION
IMPACTS TO
NATURE
AND SOCIETY
PRINCIPAL RISK
FACTORS/IMPACT
ON EQUINOR
KPI/
MONITORING
INDICATOR
AMBITION
AND STATUS
Creating a diverse
and inclusive place to
work where equal
opportunities and
human capital
development is
fostered, and
discrimination is not
tolerated in any form.
Equinor employs a large
and diverse workforce
of around 22000
employees, with
operations and value
chains in some 30
countries.
 
Business integrity and
ethical misconduct
 
Policies and legislation
 
Workforce and
organisation
Inclusion index
score (%)
I: ≥80 (2025)
n
n
 
Ambition met in 2022.
 
n
 
Ambition not met in 2022.
 
n
 
Plan in place, on track to reach longer-term ambition.
 
n
 
Plan in place, not on track to reach longer-term
 
ambition.
Contextual introduction
Equinor has worked systematically with diversity and inclusion (D&I) since 2019. Overall we believe
 
our performance in 2022 has
been satisfactory, and we have focused our work on updating the D&I strategy, ambition and metrics that will enable us to strengthen
our performance in the future. The aim is to operationalise D&I further into our business
 
and embed in how we develop our people
and engage with the societies in which we operate.
 
Recent years have seen a shift in the expectations from governments, governing bodies, society
 
and employees when it comes to
companies’ social responsibility and role in D&I. To us, D&I aligns with our values, our focus on safety and our purpose as a company.
As outlined in our Code of Conduct, we do not tolerate any discrimination or harassment of colleagues,
 
or others affected by our
operations, and require everyone to be treated with fairness, respect, and dignity. Our agreement (likestillingsavtale) between the
company and union Industri Energi applies to all employees in Equinor ASA and states that we,
 
as an employer, work to ensure all
employees are treated equally regarding recruitment, pay and working conditions, training, career paths,
 
and professional
development. Equinor is committed to being transparent about our progress and we participate in
 
several external indexes and
networks. These include the SHE Index and the Bloomberg Gender Equality Index, where we have
 
committed to integrate D&I into
our business strategy and share experience and learning.
Our updated D&I ambition states “We are a diverse and inclusive organisation where everyone feels valued
 
and that they belong. Our
D&I strategy continues to build on strengthening a safe and inclusive work environment for all and
 
ensuring fair and equal
opportunities. The strategy strengthens Equinor’s social responsibility to ensure
 
a just energy transition and builds upon the
commitments we have made as part of our new value chains.
Management approach
Our D&I strategy is based on empowering the organisation to drive D&I locally, in line with national reporting requirements and local
legislative frameworks. The strategy was developed through extensive external and internal stakeholder engagement
 
and the
feedback was focused on the need for local actions, diversity representation in senior leadership,
 
and openness to talk about diversity
dimensions beyond gender. The BoD was continually kept informed about progress through formal reporting channels and meetings.
Throughout 2022 the CEC members were involved in shaping the strategy, and employees, union representatives, and members of
employee resource groups (ERGs) were included in strategy development. A separate working
 
group with Norwegian union
representatives was established and met four times throughout the year to discuss D&I
 
actions and progress. The D&I strategy is
owned by the Human Resource team. Throughout 2022, Equinor also collaborated with the Norwegian
 
Equality and Anti-
Discrimination Ombud to share best practice of how to embed Norwegian legal requirements into
 
business strategy.
 
At Equinor, we continually work to strengthen our understanding of diversity, and we use the diversity data that is available to
measure our progress. This includes gender balance, age, and nationality. We know that inclusion is the foundation to ensure a
psychologically safe work environment where everyone feels valued, respected, and that they can
 
contribute and speak up. To
monitor our progress on inclusion, we established the Inclusion Index in 2019 and work
 
systematically with initiatives that focus on our
culture and inclusion. In addition to strategy development, our key D&I actions for 2022 focused
 
on building inclusion and equity for all
our employees.
 
ERGs are voluntary, employee-led groups that come together with the aim to create a diverse and inclusive workplace, with a
particular focus on a common diversity characteristic, cause, or goal. The establishment and support for
 
ERGs is important for Equinor
to learn about opportunities and challenges linked to equality and equity, and ensure we set actions that remove barriers for
individuals who identify as part of underrepresented groups. In 2022, we focused on
 
senior sponsorship of our ERGs and formalised
D&I awareness days. A governance structure for ERGs was developed and will be implemented
 
in 2023.
Equinor, Annual Report on Form 20-F 2022
 
65
We continuously work on risks related to discrimination and harassment. In 2022, we identified
 
a small increase in the number of
sexual harassment cases. This increase was taken very seriously, and significant actions and initiatives were put in place. This
included awareness sessions for leaders, safety moments for general use, and as a topic in the
 
quarterly Safety Wheel. The annual
global people survey (GPS) results were further analysed to determine targeted actions. The actions
 
focused on increasing
awareness of what constitutes sexual harassment, and ensuring people feel safe to speak
 
up and report inappropriate actions and
behaviour. In 2023, we intend to continue using metrics to identify signals that may imply discrimination and harassment. One such
metric includes the question about “Zero tolerance for discrimination and harassment” in the GPS which we
 
continually monitor.
We focus on strengthening inclusion of employees who identify as LGBTQ+ and increasing allyship. In
 
2022, we offered inclusive
language training (Rosa kompetanse) through the Norwegian Organisation for Sexual and Gender
 
Diversity (FRI) to our HR,
communication and recruitment department, and we are finding ways to provide this training to other groups
 
of employees in 2023.
Our focus on safety and inclusion for all LGBTQ+ colleagues was strengthened in line with
 
local Pride events. Senior leadership
communication, safety-focused deliverables, and employee engagement were ongoing throughout the year. The Pride Makers ERG
increased its activity both internally and externally and gained more members.
 
As part of our renewables value chain, Equinor made commitments related to D&I which include
 
a focus on ethnicity. This work will
continue in 2023. Our ERG, Black in Equinor further grew its membership and activity that increased
 
engagement and knowledge
about ethnicity and discrimination, with the aim of strengthening inclusion. Looking to 2023 and
 
beyond, we have identified the need to
include further work on diversity dimensions as part of our D&I roadmap, such as inclusion
 
of people with disabilities, religion, caring
responsibilities, and pregnancy/parental leave. Our updated D&I strategy will help us work more systematically
 
on inclusion across all
diversity dimensions.
Building a diverse pipeline
Our focus on building a diverse employee pipeline starts with our engagement with students
 
and young people in the locations where
we operate. Through our sponsorship programmes, partnerships, and networks we aim to help
 
shape and build a more diverse talent
pool for the future. This work is also aligned with our responsibility to ensure a just energy transition.
 
Our focus is on engaging youth
and students through programmes
 
and events that relate to science, technology, engineering, and mathematics (STEM) subjects.
This includes initiatives that target girls and women.
 
Building a robust, sustainable, and diverse pipeline is important to us at Equinor. D&I is integrated in our people processes, from how
we recruit, manage talent and succession, to leadership assessment and deployment. D&I is embedded
 
in how we work with our
people, and part of our Annual Wheel for talent and succession reviews. Diversity representation and
 
balance is discussed when
building teams, identifying talent, and building succession pipelines. Diversity is also considered
 
when we run our leadership
assessments and when selecting employees for our leadership development courses.
In 2022, we hired almost 2,000 new employees and, together with our recruitment partner, we selected a diverse pool of candidates,
with particular focus on gender and nationality. We provided hiring managers with recruitment training with the aim to ensure fair and
unbiased assessment of all applicants. We work systematically to be an attractive employer and,
 
in 2022, Equinor was ranked the
most attractive employer for engineering students in Norway, with an increase in score from female students. We have a 50:50 global
ambition for gender and nationality (Norwegian and other than Norwegian) for our corporate graduate
 
programme, and an ambition of
a one-third female share for our apprenticeship programme in Norway. A new Human Resource IT system will be implemented
throughout 2023-2024 which will give us the opportunity to further improve our recruitment
 
processes and limit biases. We are further
re-evaluating our recruitment strategy for the future, and work will commence in 2023.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
66
 
Equinor, Annual Report on Form 20-F 2022
 
Performance disclosure
 
Indicators
Boundary
Unit
2022
2021
2020
2019
2018
Inclusion Index
Equinor
Group
number
77
77
78
77
76
Diversity and gender balance
Indicators
Boundary
Unit
2022
2021
2020
2019
2018
Gender balance ASA (percentage
female)
Equinor
ASA
%
31
31
31
31
n/r
Gender balance total females
(percentage female)
Equinor
Group
%
31
31
31
30
31
Gender balance in leadership
(percentage female)
 
·
 
Corporate Executive Committee
(CEC)
 
Equinor
Group
%
36
60
30
30
30
·
 
Leaders reporting to CEC
 
Equinor
Group
%
51
49
45
41
n/r
·
 
Business unit
 
Equinor
Group
%
37
38
35
36
35
·
 
Business sector
 
Equinor
Group
%
36
37
34
35
34
·
 
Business department
 
Equinor
Group
%
32
32
27
24
24
Nationality balance total
employees
Equinor Group
·
 
Non-Norwegians in Corporate
Executive committee (CEC)
 
Equinor
Group
%
9
40
10
20
20
·
 
Non-Norwegians reporting to
Corporate Executive committee
 
Equinor
Group
%
16
n/r
n/r
n/r
n/r
·
 
Non-Norwegian in Business Unit
leadership positions
Equinor
Group
%
28
29
35
31
27
·
 
Non-Norwegians in Business
Sector leadership positions
 
Equinor
Group
%
27
29
29
28
29
·
 
Non-Norwegians in Business
Department leadership positions
 
Equinor
Group
%
16
18
18
22
20
Earnings ratio - base salary
(women:men)
 
Equinor
ASA
%
100
99
98
98
97
Earnings ratio - total compensation
(women:men)
Equinor
ASA
%
87
86
n/r
n/r
n/r
Employees per category
 
in
Norway
 
(percentage of women)
Equinor
Group
 
 
 
 
 
 
Operation and Support
 
Equinor
Group
%
23
24
n/r
n/r
n/r
Associate
 
Equinor
Group
%
46
49
n/r
n/r
n/r
Professional
 
Equinor
Group
%
45
46
n/r
n/r
n/r
Principal and Support
 
Equinor
Group
%
34
33
n/r
n/r
n/r
Leading
 
Equinor
Group
%
29
29
n/r
n/r
n/r
Manager and Executive
 
Equinor
Group
%
32
31
n/r
n/r
n/r
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
67
Diversity in early talent
programmes
Programme
Gender balance
(female:male)
Nationality balance
(non-
Norwegian:Norwegian
Hired
Target
Hired
Target
Graduates 2022
42:58
50:50
48:52
50:50
Apprentices 2022
36:64
30/70
1
N/A
N/A
1
The apprenticeship program targets are set aligned to the
 
gender share studying technical fields in Norwegian
 
upper secondary
schools.
Employment
Indicators
Boundary
Unit
2022
2021
2020
2019
2018
Part-time workers (share of women)
Equinor
ASA
%
 
73
 
n/r
n/r
 
n/r
 
n/r
 
Temporary
 
workers (share of women)
Equinor
ASA
%
 
34
 
n/r
n/r
 
n/r
n/r
Involuntary part-time
 
(number of
employees)
Equinor
ASA
number
 
 
0
 
n/r
n/r
 
n/r
n/r
Involuntary part-time
 
(share of
women)
Equinor
ASA
%
 
0
 
n/r
n/r
 
n/r
n/r
Equinor continued hiring temporary employees in 2022. The number of summer interns and apprentices, which
 
is included in this
category, was not significant (under 2%).
Norwegian statutory parental leave, Equinor ASA 2022
Number of
employees
Average
weeks
Median
number of
weeks
Female
133
18
16
Male
465
12
13
The numbers above include both statutory paid and employee
 
requested unpaid parental leave.
Permanent employees in the Equinor group
as of 31 December 2022
Geographical
region
Number of employees
2022
2021
2020
Norway
19,082
18,237
18,238
Rest of Europe
1,243
1,427
1,381
Africa
64
63
73
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
68
 
Equinor, Annual Report on Form 20-F 2022
 
Asia
96
80
68
North America
697
667
882
South America
754
652
603
Total
21,936
21,126
21,245
Total workforce by
 
region and employment type in the Equinor group in
 
2022
as of 31 December 2022
Geographical region
Permanent
employees
Consultants
Total
workforce(1)
Consultants
(%)
Norway
19,082
1,292
20,374
6
Rest of Europe
1,243
28
1,271
2
Africa
64
2
66
3
Asia
96
19
115
17
North America
697
52
749
7
South America
754
29
783
4
Total
21,936
1,422
23,358
6
Non-OECD
932
49
981
0
(1)
 
Contractor personnel, defined as third-party service providers
 
who work at our onshore and offshore
operations, are not included.
 
Performance evaluation
 
1.
 
Inclusion Index
To leverage the diversity we have in Equinor, we aim to ensure a safe and inclusive culture for all. Since the establishment of the
inclusion index in 2019, Equinor has used this data to determine actions and opportunities to
 
strengthen our culture. In 2022, the
inclusion index level remained at 77. Systematic follow up of these results will take place
 
early 2023 to determine actions that aim
to strengthen inclusion.
2.
 
Diversity in leadership
Equinor works systematically to build a sustainable, robust, and diverse leadership pipeline that feeds
 
through to diverse
leadership
 
teams. Our focus has been on monitoring gender balance and nationality, while continually working to set up teams
that, together, represent diversity beyond these two dimensions. Our systematic focus on developing female leaders is reflected
in the continued increase in female leadership over the years, with 51% females among leaders
 
reporting to the Corporate
Executive Committee in 2022.
 
We continue to focus on representation of nationalities other than Norwegian in our leadership to
ensure we represent our global operations. To strengthen our long-term systematic focus on diversity in leadership, a new D&I
KPI will be introduced in 2023, measuring gender balance and nationality representation in top leadership
 
levels. The KPI will set
the expectation for leaders across Equinor to focus on diversity in their talent and succession
 
planning. We further continue to
work systematically with gender balance across our organization and have identified the need
 
to set targets and ambitions for
gender balance more locally in our organisation. This approach is part of operationalising our D&I strategy
 
in 2023.
3.
 
Diversity in talent programs
Equinor, Annual Report on Form 20-F 2022
 
69
Equinor continues to invest in our emerging talents through our graduate and apprenticeship programmes. We focus on diversity
in our early talent programs and have set targets in terms of gender and nationality. In 2022, we welcomed 130 graduates,
representing 32 nationalities. In Norway we welcomed 169 apprentices. This year we
 
saw an increase in female apprentices with
36%, exceeding our gender target of 30% female. We plan to strengthen our gender target for next year to
 
ensure we continue
this trend in the future. We also offered a summer internship programme to 172 students, representing 20 nationalities
4.
 
Gender pay gap
Equinor publishes the earnings ratio between males and females for both total compensation and
 
base pay. Norwegian
authorities require reporting on full breakdown of earning ratios in all major Equinor locations by
 
Equinor’s job structure every
other year. Equinor will report on this data annually to strengthen transparency on our gender pay gap. For 2022, we are
 
pleased
to see that the gender pay gap for base pay is 0 for Equinor ASA. This reflects the ongoing
 
work to ensure gender-neutral pay
decisions. In Equinor ASA, we continue to see a difference in total compensation. Our analysis shows that a key driver
 
for this
differential is the higher representation of males in skilled offshore and other operational positions. These roles are typically
compensated with a range of additional elements beyond base salary, such as offshore allowances or shift allowances, as well
as overtime payments. Such allowances are directly linked to the specific job an
 
individual performs, regardless of gender. The
gender imbalance in these roles compared to non-operational onshore roles results in a wider
 
pay gap for total compensation
than with base salary. We have identified the need to do further analysis on the pay gap in our global locations where there is a
larger gap compared to Equinor ASA. Further details on our gender pay gap reporting is
 
available in the Equinor data hub.
Equinor has worked systematically with D&I since 2019. Overall, we believe our performance in 2022
 
has been satisfactory, with a
focus on updating the D&I strategy, ambition and metrics relevant to further integration of D&I in our business and strengthening our
future performance.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
70
 
Equinor, Annual Report on Form 20-F 2022
 
2.2 High value
Group analysis
2022 witnessed an unprecedented energy crisis in Europe which was exacerbated by Russia’s invasion of Ukraine,
 
causing further
disruption to the energy markets. Tight energy markets, coupled with increased demand, have led to a prolonged period of
 
extremely
high commodity prices, in particular gas which peaked at around 90 USD/MMBtu in August 2022.
In response to the conflict initiated in February 2022, Equinor took decisive action
 
to withdraw from the Russian market and exit all
assets in the country. This resulted in an impairment recognised in relation to the Russian assets of USD 1,083 million. All exit
activities were concluded within the year, and Equinor has not planned for any new investments in the country as part of its future
strategy.
During the year, Equinor achieved some notable operational milestones, including the restart of Snøhvit and Peregrino in mid-year
and Peregrino phase 2 coming on stream in the fourth quarter. All of which provided strong contributions towards offsetting the oss of
production from the Russia exit.
In response to the energy crisis in Europe, gas production was accelerated on some NCS assets
 
due to a change from gas injection
to gas export. This significantly impacted the gas production for the year from E&P Norway, increasing by 8%, and also contributed to
a global 2% increase in gas production for 2022 compared to 2021.
 
Despite the increase in gas production, restart activity and new assets coming on stream, total liquids and gas
 
production reduced
versus 2021. Equinor’s exit from Russia as announced early in 2022 and turnaround
 
activity in the US during the year, coupled with
the prior year’s divestment of Bakken, resulted in reduced production levels for
 
the full year 2022 compared to the prior year.
Results
Condensed income statement under IFRS
For the year ended 31 December
(in USD million)
2022
2021
Change
Revenues
149,004
88,744
68%
Net income/(loss) from equity accounted investments
620
259
>100%
Other income
1,182
1,921
(38%)
Total revenues and other income
150,806
90,924
66%
Purchases [net of inventory variation]
(53,806)
(35,160)
53%
Operating, selling, general and administrative expenses
(10,593)
(9,378)
13%
Depreciation, amortisation and net impairment losses
(6,391)
(11,719)
(45%)
Exploration expenses
(1,205)
(1,004)
20%
Net operating income/(loss)
78,811
33,663
>100%
Net financial items
(207)
(2,080)
90%
Income/(loss) before tax
78,604
31,583
>100%
Income tax
(49,861)
(23,007)
>100%
Net income/(loss)
28,744
8,576
>100%
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
71
Significantly elevated realised prices and optimised product split have balanced the reduced production
 
levels and are responsible for
the significant increase in
net operating income
 
for the full year 2022 relative to 2021.
Strong results were recorded from European gas and power sales optimisation and trading, as well as
 
high refining margins and high
clean spark spread positively contributing to the overall business results in 2022 relative to the
 
same periods in the prior year.
While price realisation has driven an increase in margins, Equinor has also witnessed inflationary
 
pressures increasing its
operating
expenses
. Costs pertaining to electricity, well maintenance and environmental taxes were the main contributors to this increase. The
growth in
operating expenditure
 
is partially masked by the strengthening of the USD against the NOK.
During 2022
depreciation, amortisation and net impairment losses
reduced by USD 5,328 million to USD 6,391 million. This
movement included a USD 3,339 million net impairment reversal recognised in the year which was
 
mainly due to updated estimates of
value in use of property, plant and equipment impacted by internal forecast on cost, production profiles and commodity prices.
 
The
impairment recognised in the E&P International segment related to Equinor’s
 
decision to exit Russia was more than offset by
impairment reversals primarily related to E&P Norway price changes and gas export strategy, E&P USA Gulf of Mexico assets, E&P
International production optimisation profile on Mariner and refinery margin assumptions in the MMP
 
segment. For more information,
see note 14 to the Consolidated financial statements.
The strengthening of the USD against the NOK significantly impacted
net financial items
 
in the year. The positive development of
USD 1,873 million was mainly due to a net foreign exchange gain of USD
 
2,088 million in 2022, driven by the strengthening of the
USD against NOK, compared to a gain of USD 47 million in 2021. In 2022, interest
 
income and other financial items were USD 1,070
million higher than in 2021 due to an increase in short-term interest rates. This was offset by an increase
 
in losses on financial
derivative instruments of USD 1,037 million, resulting from an increase in long-term interest rates.
Income taxes
 
increased from USD 23,007 million in 2021 to USD 49,861 million in 2022. This is
 
equivalent to a positive tax rate of
63.4% for 2022, reduced from 72.8% in 2021.
After a history of significant losses, Equinor are now recording profits in the US. Projected future
 
taxable income demonstrates that it
is probable that the unused tax losses carried forward could be utilised in the near
 
future. The tax value of the unused accumulated
losses has been recognised as a deferred tax asset of USD 2.7 billion, with a corresponding
 
decrease in income taxes of USD 2.8
billion resulting in a low reported effective tax rate compared to last year. For further information see note 11 Income taxes to the
Consolidated financial statements.
A high net income of USD 28,744 million was recorded for 2022 compared to USD 8,576 million
 
for 2021 and a net loss of USD 5,496
million in 2020.
Capital distribution
The strong financial performance of 2022 allowed Equinor to increase its quarterly dividend to total
 
USD 2,814 million ordinary
dividends in the year and USD 6,247 million extraordinary dividends (2021: 2,939 million annual
 
ordinary dividend).
Ordinary dividend per share (in USD)
Extraordinary dividend per share (in USD)
Fiscal year
Q1
Q2
Q3
Q4
Sum
Q1
Q2
Q3
Q4
Sum
2020
0.09
0.09
0.11
0.12
0.41
-
-
-
-
-
2021
0.15
0.18
0.18
0.20
0.71
-
-
-
0.20
0.20
2022
0.20
0.20
0.20
0.30
0.90
0.20
0.50
0.70
0.60
2.00
For the fourth quarter of the year, the BoD proposes to the annual general meeting a cash dividend of USD 0.30 per share, and an
extraordinary quarterly dividend of USD 0.60 per share. Considering the proposed dividend, USD 18,485 million will
 
be allocated to
retained earnings in the parent company.
For 2022, Equinor initiated a USD 5,000 million share buy-back programme which was increased
 
to USD 6,000 million later in the
year. The 2022 share buy-back programme started with the first tranche in February 2022 and ended with the fourth tranche, which
was completed in January 2023. The Norwegian State share related to the second, third and fourth tranches
 
of the 2022 share buy-
back programme and the first tranche of the 2023 share buy-back programme, amounting to
 
USD 4,020 million, will be redeemed in
2023. Redemption is subject to approval in the annual general meeting in May 2023.
For further information see note 20 Shareholders’ equity and dividends to the Consolidated financial
 
statements.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
72
 
Equinor, Annual Report on Form 20-F 2022
 
Review of cash flows
Consolidated statement of cash flows
Full year
(in USD million)
2022
2021
Cash flows provided by operating activities
 
 
35,136
 
 
28,816
 
Cash flows used in investing activities
 
(15,863)
 
(16,211)
Cash flows provided by/(used in) financing activities
 
(15,414)
 
(4,836)
Net increase/(decrease) in cash and cash equivalents
 
3,860
 
 
7,768
 
Cash flows provided by operating activities
Total operating cash flow has increased from USD 28,816 million in 2021 to USD 35,136 million in 2022. This increase is due to
strong financial results primarily driven by high commodity prices witnessed throughout the year
 
combined with stable production,
which is partially offset by a corresponding increase in tax payments of USD 35,268 million.
Cash flows used in investing activities
 
Cash flow used in investing activities has remained relatively consistent with the prior
 
year.
Cash flows used in financing activities
A significant increase in shareholder capital distribution contributed to cash flow used in financing
 
activities, increasing by USD 10,577
million from USD 4,836 million in 2021 to USD 15,414 million in 2022. In addition, Equinor
 
increased payment of short-term debt, and
experienced increased collateral payments relative to the prior year due to increased margin
 
requirements for exchange-traded
derivatives.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
73
Balance sheet and financial indicators
Non-current assets
The sum of equity-accounted investments and non-current segment assets was USD 64,414 million for
 
the year ending 31 December
2022, compared to USD 71,213 million for the year ending 31 December 2021. The decrease in non-current assets
 
primarily relates to
increased discount rates and strengthening of the USD versus the NOK.
Financial indicators
 
For the year ended 31 December
(in USD million)
2022
2021
Gross interest-bearing debt
 
1)
32,168
36,239
Net interest-bearing debt before adjustments
(13,288)
867
Net debt to capital employed ratio*
 
2)
(32.6%)
2.2%
Net debt to capital employed ratio adjusted, including lease
 
liabilities*
 
3)
(14.3%)
7.7%
Net debt to capital employed ratio adjusted*
 
3)
(23.9%)
(0.8%)
Cash and cash equivalents
15,579
14,126
Current financial investments
29,876
21,246
1)
Defined as non-current and current finance debt.
2)
As calculated based on IFRS balances. Net debt
 
to capital employed ratio is the net debt divided
 
by capital employed. Net debt is interest-
bearing debt less cash and cash equivalents and
 
current financial investments. Capital employed is net
 
debt, shareholders' equity and
minority interest.
3)
In order to calculate the net debt to capital
 
employed ratio adjusted, Equinor makes adjustments
 
to capital employed as it would be
reported under IFRS. Restricted funds held as
 
financial investments in Equinor Insurance AS and
 
Collateral deposits are added to the net
debt while the lease liabilities are taken out of
 
the net debt.
 
 
74
 
Equinor, Annual Report on Form 20-F 2022
 
Gross interest-bearing debt
Gross interest-bearing debt was USD 32.2 billion and USD 36.2 billion at 31 December 2022
 
and 2021, respectively. The USD 4.1
billion net decrease from 2021 to 2022 was due to the decline in current and non-current finance
 
debt and lease liabilities. Current
finance debt and lease liabilities decreased by USD 768 million, mainly due to a decrease in the
 
utilisation of the US Commercial
Paper programme, offset by an increase in the current portion of long-term debt, as four bonds will be repaid in 2023. Non-current
finance debt decreased by USD 3.3 billion due to reclassification of non-current debt to current debt, currency
 
effects and one repaid
bond in 2022 of USD 0.3 billion. The weighted average annual interest rate on finance debt was
 
3.29% and 3.33% at 31 December
2022 and 2021, respectively. Equinor’s weighted average maturity on finance debt was nine years at 31 December 2022 and ten
years at 31 December 2021.
Net interest-bearing debt
Net interest-bearing debt before adjustments was negative USD 13.3 billion and positive USD
 
0.9 billion at 31 December 2022 and
2021, respectively. The decrease of USD 14.2 billion from 2021 to 2022 was mainly related to an increase in cash and cash
equivalents of USD 1.4 billion, a USD 8.6 billion increase in current financial investments
 
and a decrease in gross interest-bearing
debt of USD 4.1 billion.
The net debt to capital employed ratio*
The net debt to capital employed ratio* before adjustments was -32.6% and 2.2% in 2022 and 2021, respectively.
The net debt to capital employed ratio adjusted* was -23.9% and -0.8% in 2022 and 2021, respectively.
The 34.8 percentage point decrease in net debt to capital employed ratio* before adjustments from
 
2021 to 2022 was mainly related
to the reduction of net interest-bearing debt of USD 14.2 billion.
The 23.1 percentage points decrease in net debt to capital employed ratio adjusted* from 2021 to
 
2022 was related to the decline in
net interest-bearing debt adjusted of USD 10.1 billion, offset by an increase in capital employed adjusted* of USD
 
4.9 billion.
Return on average capital employed (ROACE)*
 
The return on average capital employed (ROACE)*
 
was 55.2% in 2022, compared to 22.7% in 2021. The change from 2021 was
mainly due to the increase in adjusted earnings* after tax.
Cash, cash equivalents and current financial investments
Cash and cash equivalents were USD 15.6 billion and USD 14.1 billion at 31 December 2022
 
and 2021, respectively. See note 19
Cash and cash equivalents to the Consolidated financial statements for information concerning restricted
 
cash. Current financial
investments, which are part of Equinor’s liquidity management, amounted to USD
 
29.9 billion and USD 21.2 billion at 31 December
2022 and 2021, respectively.
Continued operation
In accordance with §3-3a of the Norwegian Accounting Act, the board of directors confirms that
 
the going concern assumption on
which the financial statements have been prepared is appropriate.
Group outlook
●
Organic capital expenditures*
 
are estimated at USD 10-11 billion for 2023 and an annual average of around USD 13 billion for
2024-2026
3
.
●
Production
for 2023 is estimated to be around 3% above the 2022
 
level.
●
 
Equinor’s ambition is to keep the
unit of production cost
 
in the top quartile of its peer group.
●
Scheduled maintenance activity
 
is estimated to reduce equity production by around 45 mboe per day for the full year
 
of 2023.
These forward-looking statements reflect current views about future events and are, by their nature, subject
 
to significant risks and
uncertainties because they relate to events and depend on circumstances that will
 
occur in the future. Deferral of production to create
future value, gas off-take, the timing of new capacity coming on stream and operational regularity and levels of industry
 
product
supply, demand and pricing represent the most significant risks related to the previous production guidance. Our future financial
performance, including cash flow and liquidity, will be affected by the extent and duration of the current market conditions and the
development in realised prices, including price differentials and other factors discussed elsewhere in the report.
 
For further
information, see section 5.10, Forward-looking statements.
3
 
USD/NOK exchange rate assumptions of 10.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
75
Operational data
For the year ended 31 December
Operational data
2022
2021
2020
22-21 change
21-20 change
Prices
Average Brent oil price (USD/bbl)
101.2
70.7
41.7
43%
70%
E&P Norway average liquids price (USD/bbl)
97.5
67.6
37.4
44%
81%
E&P International average liquids price (USD/bbl)
92.0
67.6
38.1
36%
77%
E&P USA average liquids price (USD/bbl)
81.0
58.3
31.3
39%
86%
Group average liquids price (USD/bbl)
94.1
66.3
36.5
42%
82%
Group average liquids price (NOK/bbl)
906
570
343
59%
66%
E&P Norway average internal gas price (USD/mmbtu)
31.2
14.43
2.26
>100%
 
>100%
 
E&P USA average internal gas price (USD/mmbtu)
 
5.6
2.89
1.32
92%
>100%
 
Average invoiced gas prices - Europe (USD/mmbtu)
33.4
14.60
3.58
>100%
 
>100%
 
Average invoiced gas prices - North America (USD/mmbtu)
 
5.9
3.22
1.72
83%
87%
Refining reference margin (USD/bbl)
 
14.5
4.0
1.5
>100%
 
>100%
 
Entitlement production (mboe per day)
E&P Norway entitlement liquids production
605
643
630
(6%)
2%
E&P International entitlement liquids production
203
207
236
(2%)
(12%)
E&P USA entitlement liquids production
114
128
163
(11%)
(22%)
Group entitlement liquids production
922
978
1,029
(6%)
(5%)
E&P Norway entitlement gas production
782
721
685
8%
5%
E&P International entitlement gas production
32
40
42
(19%)
(6%)
E&P USA entitlement gas production
165
193
181
(14%)
6%
Group entitlement gas production
980
954
908
3%
5%
Total entitlement liquids and gas production
1,901
1,931
1,938
(2%)
(0%)
Equity production (mboe per day)
E&P Norway equity liquids production
605
643
630
(6%)
2%
E&P International equity liquids production
281
291
303
(4%)
(4%)
E&P USA equity liquids production
127
142
187
(11%)
(24%)
Group equity liquids production
1,013
1,076
1,120
(6%)
(4%)
E&P Norway equity gas production
782
721
685
8%
5%
E&P International equity gas production
47
51
49
(7%)
5%
E&P USA equity gas production
197
231
216
(15%)
7%
Group equity gas production
1,026
1,003
950
2%
6%
Total equity liquids and gas production
2,039
2,079
2,070
(2%)
0%
Liftings (mboe per day)
Liquids liftings
914
980
1,050
(7%)
(7%)
Gas liftings
1,009
989
941
2%
5%
Total liquids and gas liftings
1,923
1,969
1,991
(2%)
(1%)
Production cost (USD/boe)
Production cost entitlement volumes
6.5
5.8
5.1
12%
14%
Production cost equity volumes
 
6.1
5.4
4.8
13%
13%
Power generation
Total power generation (GWh) Equinor share
2,661
1,562
1,662
70%
(6%)
Renewable power generation (GWh) Equinor share
1,649
1,562
1,662
6%
(6%)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
76
 
Equinor, Annual Report on Form 20-F 2022
 
Sales volumes
Sales volumes include lifted entitlement volumes, the sale of SDFI volumes and the marketing of third-party
 
volumes. In addition to
Equinor’s own volumes, we market and sell oil and gas owned by the Norwegian State
 
through the Norwegian State's share in
production licences. This is known as the State's Direct Financial Interest or SDFI. For
 
additional information, see section 5.1 Board
statement on corporate governance – subsection 4. Equal treatment of shareholders and transactions with
 
close associates, and note
7 Total revenues and other income to the Consolidated financial statements.
The following table shows the SDFI and Equinor sales volume information on crude oil and natural
 
gas for the periods indicated.
 
For the year ended 31 December
Sales Volumes
2022
2021
2020
Equinor
1)
Crude oil (mmbbls)
2)
334
358
384
Natural gas (bcm)
58.6
57.4
54.8
Combined oil and gas (mmboe)
702
719
729
Third-party volumes
3)
Crude oil (mmbbls)
2)
284
286
318
Natural gas (bcm)
7.2
7.0
8.1
Combined oil and gas (mmboe)
330
330
369
SDFI assets owned by the Norwegian State
4)
Crude oil (mmbbls)
2)
132
143
132
Natural gas (bcm)
42.9
41.7
38.4
Combined oil and gas (mmboe)
402
406
374
Total
Crude oil (mmbbls)
2)
750
787
835
Natural gas (bcm)
108.7
106.2
101.3
Combined oil and gas (mmboe)
1,434
1,455
1,472
1)
The Equinor volumes included in the table above
 
are based on the assumption that volumes sold were
 
equal to lifted volumes in the
relevant year. Volumes lifted by E&P International or E&P USA but not sold by MMP, and volumes lifted by E&P Norway, E&P
International or E&P USA and still in inventory
 
or in transit may cause these volumes to differ from the
 
sales volumes reported elsewhere
in this report by MMP.
2)
Sales volumes of crude oil include NGL and
 
condensate. All sales volumes reported in the table
 
above include internal deliveries to our
manufacturing facilities.
3)
Third-party volumes of crude oil include both volumes
 
purchased from partners in our upstream operations
 
and other cargos purchased
in the market. The third-party volumes are purchased
 
either for sale to third parties or for our own use.
 
Third party volumes of natural
gas include third-party LNG volumes
4)
The line item SDFI assets owned by the Norwegian
 
State includes sales of both equity production and
 
third-party.
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
77
Sales prices
The following table presents realised sales prices.
Realised sales prices
Norway
Eurasia
 
excluding
Norway
Africa
Americas
Year ended 31 December 2022
Average sales price oil and condensate in USD per bbl
102.0
89.7
100.9
90.0
Average sales price NGL in USD per bbl
64.2
NA
59.7
34.9
Average sales price natural gas in USD per mmBtu
33.4
25.8
8.4
5.9
Year ended 31 December 2021
Average sales price oil and condensate in USD per bbl
70.0
67.0
71.0
65.7
Average sales price NGL in USD per bbl
52.5
51.8
48.9
29.5
Average sales price natural gas in USD per mmBtu
14.6
15.4
6.9
3.2
Year ended 31 December 2020
Average sales price oil and condensate in USD per bbl
39.7
37.4
41.1
36.1
Average sales price NGL in USD per bbl
25.6
30.3
23.3
11.8
Average sales price natural gas in USD per mmBtu
3.6
3.2
3.9
1.7
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
78
 
Equinor, Annual Report on Form 20-F 2022
 
High value – overview of material topics
 
Our strategic pillar, “High Value”,
 
reflects our commitment to prioritising value in everything we do. This includes creating
 
value for our
customers, shareholders and broader society. Value can be measured by “
how
” we perform and operate in addition to “
what
” we
produce and achieve.
In this chapter, the strategic pillar of High value is covered by the material topics; Efficient and predictable operations, Profitable
portfolio, Value creation for society, and Integrity and anti-corruption. The indicators in the table shown are key in monitoring Equinor’s
value performance.
 
HIGH VALUE
KPI/MONITORING
INDICATOR
2022 AMBITION
(TARGET YEAR)
STATUS
PERFORMANCE
2022
2021
EFFICIENT AND PREDICTABLE
 
OPERATIONS
Equity production liquids and gas
(mboe per day)
2022 outlook guiding ˜2% above
2021
1,3
n
Growth 0%
(2039)
2079
Production cost equity volumes
(USD/boe)
<5 USD/bbl (2021-2026)
1,2
n
5.6
2
5.4
PROFITABLE PORTFOLIO
Return on Average Capital Employed*
(ROACE) (%)
>14% yearly (2022-2030)
1,4
n
55.2
22.7
Relative Total Shareholder Return
(Relative TSR) (quartile)
Above average in ranking
among peers
1
n
6 of 12
2 of 12
Relative ROACE* (peer group rank)
First quartile in ranking among
peers
1
n
1 of 12
2 of 12
Organic Capex* (billion USD)
2022 outlook guiding
 
USD 10
1
n
8.3
5
7.9
VALUE CREATION
 
FOR SOCIETY
Payments to goverments (billion USD)
Not applicable
49.2
11.8
Share of procurement spend locally (%)
Not applicable
88.7
91.4
INTEGRITY AND ANTI-CORRUPTION
Confirmed corruption cases (number of)
0 (2022)
n
0
0
Employees who signed-off the Code of Conduct
(%)
≥95% (2022)
n
95
84
Text in bold:
Key performance indicator.
 
1
 
Outlook and ambitions presented at CMU 2022 or in Annual
 
report 2021 (forward looking updated in CMU).
 
2
USD 2021 real base.
 
3
Rebased for portfolio measures.
 
4
Based on 2022 CMU price scenario (65 USD/bbl).
5
Adjusted to USD/NOK exchange rate assumption
 
in the Outlook presented at CMU 2022.
n
 
Ambition met in 2022.
 
n
 
Ambition not met in 2022.
 
n
 
Plan in place, on track to reach longer-term ambition.
 
n
 
Plan in place, not on track to reach longer-term
 
ambition.
Efficient and predictable operations
The core of our business is energy provision to our customers. Optimal operational performance to
 
drive production and how we get
energy to our customers ultimately drives the business and serves the most people. In the current
 
situation of economic crisis and
tight energy supply with high demand efficient and predictable operations are of particular importance. Equity production reflects
 
our
ability to produce at a high level over time and through different phases of activity. Production cost equity volumes indicate how cost
efficient our production operations are, thereby assessing the value of our volumes.
 
Profitable portfolio
To ensure the business is future-proof, robust and attractive to our shareholders now and through the energy transition, our portfolio
and the development of that portfolio needs to be carefully managed and evaluated to ensure profitability
 
now and for the future.
Organic capex* tracks our investment into our portfolio,
 
which is carefully spent using targeted investment criteria. Return on
 
average
capital employed* and relative shareholder return are important ways to track value generated
 
from the portfolio and our ability to
competitively distribute that to our shareholders.
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
79
Value creation for society
Equinor can influence socioeconomic development by creating job opportunities, local spending, and taxes. Return
 
of value to the
wider community can be assessed through taxes paid, of which Equinor contributes significantly
 
due to high earnings on the NCS and
a share of procurement spent locally.
 
Integrity and anti-corruption
Integrity and anti-corruption signify the importance Equinor places on “how” we deliver in a high-value manner. Ethical business
practices across the company’s global reach are of paramount importance, measured through confirmed corruption cases. For
Equinor to speak with one voice in all we do, we need to ensure alignment on our values, which
 
is monitored through a code of
conduct sign-off.
 
The Equinor strategy assumes a sustainable high value strategic pillar achieved through the strategic
 
priorities focusing on optimising
oil and gas initiatives while focusing on high value growth in renewables and new market
 
opportunities in LCS.
 
exhibit154p55i1 exhibit154p49i1 exhibit154p80i3 exhibit154p49i0 exhibit154p49i0 exhibit154p49i0
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
80
 
Equinor, Annual Report on Form 20-F 2022
 
2.2.1 Efficient and predictable operations
TOPIC
DESCRIPTION
IMPACTS TO
NATURE
AND SOCIETY
PRINCIPAL RISK
FACTORS/IMPACT
ON EQUINOR
KPI/
MONITORING
INDICATOR
AMBITION
AND STATUS
Optimisation and
management of
operations,
turnarounds, and
technological
innovation.
Europe is dependent on
companies which can
take the role as a
reliable and robust
energy producer, more
than ever before.
Equinor can impact
energy security and
sustainability in Europe,
both in the short- and
medium-term.
 
Project delivery and
operations
 
Joint arrangements and
contractors
 
Competition and
technological innovation
 
Digital and cyber security
 
Crisis management,
business continuity and
insurance coverage
 
Health, safety and
environmental factors
Equity production
liquids and gas
(mboe per day)
2022 outlook guiding
˜2% above 2021
n
Production cost
equity volumes
(USD/boe)
<5 USD/bbl (2021-
2026)
n
n
 
Ambition met in 2022.
 
n
 
Ambition not met in 2022.
 
n
 
Plan in place, on track to reach longer-term ambition.
 
n
 
Plan in place, not on track to reach longer-term
 
ambition.
Text in bold:
Key performance indicator.
Contextual introduction
Equinor works to safeguard efficient and reliable activities with a reduced carbon footprint per barrel, from exploration to project
development and production, together with partners and suppliers. We focus on developing prospects with
 
a low carbon intensity near
existing fields and infrastructure to optimise value creation and prolong field lifetime. Always with
 
safety and security as the highest
priority, we deliver competitive projects and world-class drilling performance. Through our technology experience, we create significant
value in project development. Our technology development and implementation will be important
 
for operational cost-efficiency and
decarbonisation going forward.
In response to the energy crisis, Equinor liaised with partners and Norwegian authorities to increase
 
gas exports to Europe through
adjusted production permits and reduced gas injection. Underpinned by safe and dependable operations, the efforts made it
 
possible
to increase the natural gas output from the NCS significantly during 2022.
Equinor executes a significant project portfolio and supports value creation through continued efficient and predictable
 
operations.
 
Solid operational performance is delivered with high gas production from the NCS supporting European
 
energy security. Peregrino in
Brazil and Hammerfest LNG are safely back in operation, and production is resumed from Njord
 
A and B. New important projects on
stream are Johan Sverdrup phase 2 on the NCS and Peregrino phase 2 in Brazil. The first
 
power from the floating offshore wind farm
Hywind Tampen was produced in the fourth quarter.
Management approach
 
Exploration
 
Continued exploration of hydrocarbons is important to maintaining long-term energy deliveries.
 
On the NCS, we increasingly explore
mature areas where discoveries can be tied into existing infrastructure. Utilising previous investments
 
contribute to improved value
creation and lower emission. Internationally we prioritise significant wells in growth and frontier
 
basins.
Equinor was awarded 26 new licences in mature areas on the NCS in January 2022 and 26 licences
 
in January 2023. We drill wells
based on the following main criteria: high profitability, short payback time and low carbon intensity. In addition, meeting a rising gas
demand from Europe, including as input to sectors such as blue hydrogen production, will require
 
exploration for new gas volumes.
Several developments tied back to existing infrastructure were brought on stream over the last
 
years, such as the Snøhvit satellite
Askeladd in 2022 and Troll phase 3 in 2021. Subsea tieback developments Kristin South, Halten East, Irpa and Verdande are
underway to add value and extend the field lifetime.
Project development
Equinor is responsible for a portfolio of 28 projects in execution, encompassing oil and gas projects combined
 
with electrification
projects to contribute to the energy transition.
 
We will reinvest in our oil and gas activity in an attractive project portfolio with an average breakeven of USD 35 per
 
barrel and a short
average payback time. We also continue to invest and grow our project portfolio within renewables and low-carbon
 
solutions. A
milestone is the first power expected in 2023 for Dogger Bank, the world’s largest offshore wind farm.
 
Equinor, Annual Report on Form 20-F 2022
 
81
We use standardised and digitised solutions to ensure the delivery of competitive projects with long-term value creation and
 
maintain
a rigorous quality and cost focus
.
With the pursuit of ‘the perfect well,’ a modern rig fleet and capitalising on economies of scale,
 
we
demonstrate world-class drilling performance. In external benchmarks, Equinor is ranked highly on the facility cost
 
index for completed
projects and drilling cost per metre.
 
We mature promising prospects towards sanction, focusing on economically viable projects with robust technical solutions
 
and the
lowest possible emissions.
 
Improvement activities are undertaken to ensure that our project deliveries remain competitive towards a digital
 
and carbon-neutral
future. The investment projects are developed in project development centres that strengthen the use of standardised
 
products and
tasks, enabling consistent use of best practices driving continuous learning and improvement for
 
project development, together with
good capacity utilisation. Fit-for-purpose digital solutions contributing to efficient and transparent decision-making and collaboration
are implemented in projects with training and roll-out in the project development centres.
We work to deploy standard procurement specifications and standardised solutions in projects to reduce costs and
 
improve efficiency,
seeking to realise portfolio synergies and unlock value through simplification, standardisation and industrialisation.
 
Digital well
deliveries and automated well control are being implemented - new ways of working to improve safety, reduce carbon footprint and
standardise the best performance. Also, we work closely with suppliers through strategic collaboration to
 
deliver projects successfully.
 
Technology is an enabler in making projects cost-efficient and profitable.
 
To contribute to efficient and reliable operations with lower
CO
2
 
emissions, we aim to deploy innovative technologies in field development within both offshore oil and gas, renewables
 
and low-
carbon solutions. Recent examples are Johan Sverdrup’s use of ‘digital twin’ and the innovative Hywind technology developed
 
by
Equinor and deployed in floating wind developments, such as Hywind Scotland and Hywind Tampen, the first floating offshore wind
farm to supply offshore oil and gas installations in operation.
 
Operations
We aim to ensure safe and efficient operations, maximising the value potential of our assets worldwide. We transform the NCS using
digital and carbon-efficient solutions with electrification on installations.
The operations of our fields on the NCS are supported by three onshore integrated operations centres
 
(IOCs), contributing to
optimisation and increased production efficiency. Digital tools ensure faster and better decisions through close interaction between
offshore operations and the onshore support centre. Furthermore, the centres strengthen our collaboration with
 
suppliers and
partners, enhance the knowledge transfer across the organisation, and benefit from economies of
 
scale. The IOCs contribute to safe
and optimal operations of our installations, identifying challenges and preventing shutdowns.
 
A separate unit within Equinor works to provide value creation for late-life fields.
 
Innovative approaches, such as using ambulating
teams has resulted in efficiency gains and eliminated backlog of critical maintenance.
We create value by increasing recovery and prolonging field life from our producing assets, capitalising on existing infrastructure.
Projects brought on stream and tied into existing infrastructure in 2022 were the fifth Johan Sverdrup
 
platform, the revamped Njord A
and storage vessel, the third Peregrino wellhead platform and a Roncador IOR project in Brazil.
 
The Peregrino field in Brazil and
Snøhvit in the Barents Sea were safely brought back into production, and the refurbished Hammerfest
 
LNG plant resumed operations
after having been suspended following the Melkøya fire in September 2020. Production
 
started on the Vito deepwater platform,
operated by Shell, in early 2023.
We worked with partners and government authorities throughout 2022 to increase gas exports to Europe through
 
increased
production permits, reduced gas injection, and optimisation of NGL to increase gas calorific
 
value. The flexibility in our gas portfolio
allowed us to transport and sell gas where it was most needed.
Laying the ground for cost-efficient and sustainable operations in the future, we electrify offshore and onshore installations. The
electric power supply is provided either through power cables from shore,
 
or by offshore wind turbines, and is operational at several
fields on the NCS. The Johan Sverdrup field, brought into production in 2019, emits
 
only 0.67 kg CO
2
 
per barrel, compared to the
global average of 15 kg per barrel, mainly owing to power supply from shore. The Hywind Tampen floating wind farm to supply
Gullfaks and Snorre started production in 2022. Work is underway to electrify other NCS fields.
 
Leveraging 25 years of operational experience and technology within carbon capture and storage
 
(CCS) on the NCS, we work to
develop solutions for CCS, expected to play a major part in the Norwegian climate solution. The
 
Northern Lights infrastructure project
for CO
2
 
transport and storage is well underway, and the development of a CO
2
 
storage at Smeaheia is under consideration.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
82
 
Equinor, Annual Report on Form 20-F 2022
 
Performance disclosure
 
KPI/MONITORING
INDICATOR
2022 AMBITION
(TARGET YEAR)
STATU
S
PERFORMANCE
2022
2021
EFFICIENT AND PREDICTABLE
 
OPERATIONS
Equity production liquids and gas
(mboe per day)
2022 outlook guiding ˜2%
above 2021
1,3
n
Growth 0%
(2039)
2079
Production cost equity volumes
(USD/boe)
<5 USD/bbl (2021-2026)
1,2
n
5.6
2
5.4
Text in bold:
Key performance indicator.
 
1
 
Outlook and ambitions presented at CMU 2022
 
or in Annual report 2021 (forward looking updated
 
in CMU).
 
2
USD 2021 real base.
 
3
Rebased for portfolio measures.
 
4
Based on 2022 CMU price scenario (65
 
USD/bbl).
n
 
Ambition met in 2022.
 
n
 
Ambition not met in 2022.
 
n
 
Plan in place, on track to reach longer-term ambition.
 
n
 
Plan in place, not on track to reach longer-term
 
ambition.
Performance evaluation
Oil and Gas production
Total equity liquids and gas production was 2,039 mboe and 2,079 mboe per day in 2022
 
and 2021, respectively. Divestment of
assets, including exit from Russian
 
assets, and natural decline contributed to the decrease. The Snøhvit, Peregrino and Njord fields
resumed production in 2022, and Johan Sverdrup phase 2 and Peregrino phase 2 started production in the fourth quarter
 
of 2022.
Lower liquid production was partially offset by increased gas production,
 
as Equinor implemented measures to increase deliveries of
natural gas to Europe.
 
Rebased for portfolio measures the equity production was flat from 2021 to 2022. The result
 
is below the guided outlook ambition of a
2% production increase, mainly due to later startup of new fields than assumed in the initial
 
guiding forecast, and operations.
 
Total entitlement liquids and gas production was 1,901 mboe per day in 2022 compared to 1,931 mboe in 2021. The production was
mainly influenced by the factors mentioned above.
Over time, the volumes lifted and sold will equal the entitlement production, but they may
 
be higher or lower in any period due to
differences between the capacity and timing of the vessels lifting our volumes and the actual entitlement
 
production during the period.
Unit Production Cost (UPC)
 
The equity Unit Production Cost (UPC) for 2022 ended on 6.1 USD/bbl (compared towards the 2021 USD
 
real base outlook
assumptions, the 2022 UPC ended at 5.6 USD/bbl). The increase in UPC from
 
2021 to 2022 is mainly related to increase in the
energy cost and CO
2
 
cost. In addition, there has been portfolio adjustments resulting in increased equity share in
 
Statfjord licence,
being a late life field with high UPC.
The UPC ambition communicated at Capital Market Update (CMU) in February 2023 is to
 
keep the UPC below 6.0 USD/bbl (USD
2022 real term) in the period from 2023-2026.
 
Renewables Power Generation
 
From 2021 to 2022, the total renewable power generation increased by 5.6 % (from 1,562
 
GWh to 1,649 GWh). The increased power
production is mainly due to a full year operation of the Guanizuil IIA solar plant in Argentina.
 
exhibit154p49i0 exhibit154p49i1 exhibit154p49i1 exhibit154p49i0 exhibit154p49i0 exhibit154p49i1
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
83
2.2.2 Profitable portfolio
TOPIC
DESCRIPTION
IMPACTS TO
NATURE
AND SOCIETY
PRINCIPAL RISK
FACTORS/IMPACT
ON EQUINOR
KPI/
MONITORING
INDICATOR
AMBITION
AND STATUS
Portfolio development
and composition to
ensure ongoing
profitability with risk
assessment and
management
of current asset base.
Having a profitable and
robust portfolio enables
Equinor to provide
longterm economic
value through job
creation, tax
contributions and
providing
 
energy.
 
Prices and markets
 
Hydrocarbon resource
base and low carbon
opportunities
 
Capital structure, finance,
and liquidity
 
Trading and supply
activities
 
Policies and legislation
 
Climate change and
transition to lower carbon
economy
Return on Average
Capital Employed*
(ROACE) (%)
>14% yearly
 
(2022-2030)
n
Relative Total
Share-holder
Return (Relative
TSR) (quartile)
Above average in
ranking among peers
n
Relative ROACE*
(peer group rank)
First quartile in ranking
among peers
n
Organic Capex*
(billion USD)
2022 outlook guiding
USD 10
n
n
 
Ambition met in 2022.
 
n
 
Ambition not met in 2022.
 
n
 
Plan in place, on track to reach longer-term ambition.
 
n
 
Plan in place, not on track to reach longer-term
 
ambition.
Text in bold:
Key performance indicator.
Contextual Introduction
 
Equinor’s portfolio delivered strong profits based on our ability to maintain stable delivery
 
of oil and gas during an energy crisis in
Europe.
 
The cost inflation and the capacity constraints in the heated supplier market will likely make
 
it more challenging to sanction and to
execute new projects going forward. The overall cost trend was stable within sanctioned
 
project developments through 2022, due to
the price conditions in existing contracts. However, the non-sanctioned project portfolio will likely be exposed to major market effects
going forward. Most cost increases are expected to come from the cost of equipment and raw materials,
 
reflecting higher commodity
prices and an increasingly heated supplier market. Following the market volatility and unpredictability, suppliers are building increased
profit risk elements into the contract quotes.
In order to maintain a profitable portfolio and reliably supply energy through the transition, Equinor is transforming
 
its portfolio to
become a broad energy company. Equinor believes that by being a leading company in the energy transition, we can not only reduce
our own CO
2
 
footprint, but also maximise value for both society and our shareholders. Building a portfolio
 
that has robust profitability
through future cycles will be essential for us to deliver on our Energy Transition Plan and provide shareholder value.
Management approach
 
Portfolio composition
Our ambition is to build a focused, carbon efficient oil and gas portfolio complemented with renewable and low-carbon solutions
 
to
create long-term value while supplying reliable energy with progressively lower emissions. Future oil and natural
 
gas prices are
uncertain and Equinor believes it is positioned to capture the upside and withstand the downside.
exhibit154p84i1 exhibit154p84i0
84
 
Equinor, Annual Report on Form 20-F 2022
 
As illustrated by the following graph, the share of gross capex*
 
in renewables and low-carbon solutions increased from 11% in 2021 to
14% in 2022. Based on current portfolio forecasts, we are progressing on our ambitions to have
 
more than 30% of our annual gross
capex* allocated to renewables and low-carbon solutions in 2025. This growth will be contingent
 
on access and profitability.
Due to the long-term nature of investments in energy projects it is expected that our rising share
 
of investments in renewable energy
projects will have an increasing impact on the oil, gas and renewables ratios in the total production
 
profile as the projects come into
operation. In 2022 Equinor produced a total of 4.3 million TJ of energy, 16 thousand TJ of which was from renewables. By 2030, we
aim to reach an installed net capacity of 12-16 GW of renewables, with the potential to produce
 
between 35 and 60 TWh annually,
while maintaining our energy production from oil and gas at around the same level as
 
today.
Investment criteria and portfolio robustness:
Equinor’s strategy is to continue to create long-term, high value growth by developing
 
a broad portfolio pipeline and applying strict
robustness criteria to investments. To maintain a valuable portfolio in different possible energy transition pathways, Equinor has a
financial framework in place addressing climate-related risks and the robustness of investment proposals.
exhibit154p85i0
 
Equinor, Annual Report on Form 20-F 2022
 
85
Investment criteria
When a project is being sanctioned, it is assessed on multiple measures:
•
 
Net present value (NPV): to bring value to the company and our shareholders.
 
•
 
Price sensitivities: to assess the impact of different prices on the investment.
 
•
 
Other considerations include: safety, security and sustainability, optionality,
 
resource efficiency and alternative cost, strategic
value, country risk, operational capacity and capability. We undertake environmental and social impact assessments for all new
projects including consideration of potential human rights impacts.
 
In addition, for oil and gas projects, the following assessments are undertaken:
•
 
Break-even price: to remain robust in low-price scenarios we use a break-even target for
 
all oil and gas projects.
 
•
 
CO
₂
 
intensity: all oil and gas projects are measured on scope 1 CO
₂
 
intensity (upstream).
 
•
 
Carbon pricing: a CO
₂
 
cost acts as an additional element of robustness, including application of Equinor’s internal
 
carbon price.
 
Equinor recognises that planned investments that are not sanctioned can have negative economic consequences
 
for connected
suppliers, partners, and end users of energy. We therefore work closely with all stakeholders, including local governments to explore
solutions that enable Equinor to proceed with investment, or alternatively to find new developers
 
or owners.
Portfolio robustness
Equinor maintains significant capex flexibility in our current portfolio, with only our sanctioned projects
 
being committed, representing
less than 50% of the total capex between 2024 and 2026. This will allow us to optimise and
 
re-prioritise our non-sanctioned projects to
ensure we continue to generate high value through cycles. The volume weighted break-even price of our upstream
 
projects coming on
stream in the next 10 years is around 35 USD/bbl. Operated projects already sanctioned have a
 
weighted average break-even price
below 30 USD/bbl (calculated from date of sanction). Despite increased competition, we maintain
 
our expectation of real base project
returns of 4% to 8% for renewables excluding the effects of farmdowns and project financing.
Portfolio Stress Test
Since 2016 Equinor has tested the resilience of its portfolio against the scenarios from
 
the IEAs World Energy Outlook (WEO) report.
WEO scenarios change from year to year and in the 2022 WEO report they were:
• Stated Policies Scenario (STEPS).
• Announced Pledges Scenario (APS).
• Net Zero Emissions by 2050 Scenario (NZE).
The WEO 2022 scenarios illustrate the wide range of possible demand for
different energy sources, including fossil fuels, nuclear and renewables.
The scenarios show that relative to 2021, oil and gas energy demand in
2050 could be 10% higher (STEPS) or 40% lower (APS). The NZE
scenario shows a significant 70% reduction in oil and gas energy demand
and relies on a rapid growth of alternative energy sources.
We test our portfolio by applying the price assumptions for oil, natural gas
and CO
2
 
tax in each of these scenarios and compare the impact towards
the value calculated at our commodity price assumptions
4
. Equinor’s
commodity price assumptions are based on management’s best estimate
of the development of relevant current circumstances and the likely future
development of such circumstances. This price-set is currently not equal
to a price-set in accordance with the achievements of the goals in the
Paris Agreement as described in the WEO Sustainability Development
Scenario, or the Net Zero Emissions by 2050 Scenario.
The Stated Policies and Announced Pledges scenarios have a median expected global temperature
 
rise by 2050 of around 1.95
℃
and 1.65
℃
 
respectively.
The Net Zero Emissions scenario is consistent with limiting global temperature rise to
 
1.5
℃
 
with a 50% probability.
4
See note 14 Impairments to the Consolidated financial statements for an overview of Equinor’s
 
long term commodity price
assumptions.
exhibit154p86i1 exhibit154p86i0
 
86
 
Equinor, Annual Report on Form 20-F 2022
 
The illustration shown displays the net present value after tax (NPV) in the WEO scenarios relative
 
to value using Equinor’s
commodity price assumptions.
Compared to last year’s report, the impact from the Stated Policies Scenario
 
has increased from 30% to 41%, and the impact from the
Announced Pledges Scenario has increased from 12% to 17%. The Net Zero Emissions Scenario
 
decreases NPV by 22%, 12% less
than last year. Our long-term strategy remains firm, however the change from last year is mainly impacted by the bridging of high
current commodity prices towards the initial WEO 2030 scenario price point. The resilience in
 
our oil and gas portfolio, combined with
our continuous focus on maintaining flexibility, positions us well towards different future scenarios and towards a sustained low-price
environment.
NPV is calculated forward looking from 2023. We assume a linear bridging between 2022 prices and the first
 
price point given by the
IEA in 2030. This bridging is consistent with methodology used in previous years. However, due to high commodity prices seen in
2022, this methodology leads to some of the IEA scenarios having higher commodity prices than
 
Equinor’s commodity price
assumptions for some years towards 2030. We further assume a linear interpolation between IEA’s price from 2030 to 2050 and that
the price in 2050 is kept constant in real terms thereafter. USD 2 per boe transportation cost for oil production is added to compare
with Brent Blend. Exploration activities are not included due to the uncertainties related to potential
 
discoveries and development
solutions. The WEO scenarios renders some volumes unprofitable, which could have implications
 
for sanctioning of new projects.
Equinor’s renewable projects are not fully influenced by the price assumptions
 
in the different scenarios, due to offtake agreements.
Furthermore, the scenarios primarily stress oil and gas prices, not reflecting the potential impact on our renewable
 
and low carbon
projects in an accelerated transition scenario. Our portfolio flexibility may help us to reduce the negative impact
 
seen in the low-price
scenarios by mitigating actions such as re-optimizing the non-sanctioned portfolio.
Carbon pricing and carbon costs
For portfolio and decision analysis, our base assumptions include a
carbon cost for all assets and projects. In countries where no such
cost exists, we use a generic cost starting from 2023. We use a
default minimum at 68 USD per tonne (real 2022), that increases to
108 USD per tonne by 2030 and stays flat thereafter.
 
In countries with
higher carbon costs, we use the country-specific cost expectations.
This carbon cost is included in investment decisions and is part of
break-even calculations when testing for profitability robustness. The
actual CO
₂
 
costs for Equinor-operated assets were USD 1,019 million
in 2022
5
.
The illustration above shows the total carbon cost in the WEO scenarios, relative to the total cost
 
using Equinor’s commodity price
assumptions, based on the same volume base. All the WEO scenarios predict lower absolute carbon
 
costs compared to Equinor’s
assumed CO
₂
 
cost. With Equinor’s ambition to reduce operated scope 1 and 2 emissions by
 
net 50% by 2030 relative to 2015, this
further supports the adaptation to a low-carbon future.
Physical Climate Risk
Equinor’s portfolio comprises offshore and onshore assets across a diverse set
of regions around the world. While the company’s core business is centred on
the NCS, the internationalisation of the oil and gas portfolio and the move
towards a broad energy company has seen an expansion in the company’s
geographic footprint.
 
The IPCC’s sixth assessment report finds that “climate
change is bringing multiple different changes in different regions – which will all
increase with further warming”. These include changes to wetness and dryness,
to winds, snow and ice, coastal areas and oceans.  To assess the exposure of
our assets to possible climate-related perils we modeled the portfolio to different
climate scenarios using data analytics software. The model assessed the
exposure of 118 assets in which Equinor has an equity interest to six climate-
related perils: wind, heat, fire, flood, hail and precipitation, providing details on
both present-day exposure and the expected change in exposure between 2020
and 2050.
5
Costs are reported for Equinor-operated assets only, on a 100% basis, cost before tax (tax deductible).
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
87
The results of the assessment can be seen in the figure above, which also shows the relative
 
book value of different clusters of assets
by reporting segment. The results show that the majority of Equinor’s assets
 
by book value are subject to a relatively low level of
present and future climate-related exposure. Those assets subject to the highest present-day exposure are offshore installations
 
in
the US Gulf of Mexico, while those with the greatest changes in exposure towards
 
2050 are the renewable installations in South
America. Similar results were found for both the RCP 4.5 and RCP 8.5 warming
 
scenarios.
 
While the assessment provides details on
the exposure of assets, it is not a direct indication of physical or financial-related risk as all Equinor
 
installations are designed with
margins to tolerate a range of meteorological conditions.
 
Installation-specific risk assessments are therefore required to assess the
climate risk and to implement mitigating measures (if required). We will continue to assess the current and future
 
exposure of our
portfolio to physical climate changes and to implement preventative and mitigating measures.
Profitable portfolio
By carefully evaluating investment criteria to develop our future portfolio and assessing our current
 
portfolio for physical climate risk
exposure, we can ensure we have resilient value creating assets able to be profitable through
 
challenging market conditions and
climate scenarios. It also empowers us with knowledge to implement any measures to ensure we
 
are profitable for the future and able
to create value for shareholders through capital allocation and distribution.
Performance disclosure
 
KPI/MONITORING
INDICATOR
2022 AMBITION
(TARGET YEAR)
STATU
S
PERFORMANCE
2022
2021
PROFITABLE PORTFOLIO
Return on Average Capital Employed*
(ROACE) (%)
>14% yearly (2022-2030)
1,4
n
55.2
22.7
Relative Total Shareholder Return
(Relative TSR) (quartile)
Above average in ranking
among peers
1
n
6 of 12
2 of 12
Relative ROACE* (peer group rank)
First quartile in ranking
among peers
1
n
1 of 12
2 of 12
Organic Capex* (billion USD)
2022 outlook guiding
 
USD 10
1
n
8.3
5
7.9
Text in bold:
Key performance indicator.
 
1
 
Outlook and ambitions presented at CMU 2022
 
or in Annual report 2021 (forward looking updated
 
in CMU).
 
2
USD 2021 real base.
 
3
Rebased for portfolio measures.
 
4
Based on 2022 CMU price scenario (65 USD/bbl).
5
Adjusted to USD/NOK exchange rate assumption in
 
the Outlook presented at CMU 2022
n
 
Ambition met in 2022.
 
n
 
Ambition not met in 2022.
 
n
 
Plan in place, on track to reach longer-term
 
ambition.
 
n
 
Plan in place, not on track to reach longer-term
 
ambition.
Performance evaluation
Investments
 
In 2022, capital expenditures, defined as Additions to PP&E, intangibles and equity accounted
 
investments in note 5 Segments to the
Consolidated financial statements, amounted to USD 10.0 billion, of which USD 8.1 billion were
 
organic capital expenditures*
(adjusted to USD/NOK exchange rate assumption in the Outlook presented at CMU 2022, organic
 
capital expenditures* were USD 8.3
billion).
 
In 2021, capital expenditures were USD 8.5 billion, as per note 5 Segments to the Consolidated financial
 
statements, of which organic
capital expenditures*
 
amounted to USD 8.1 billion.
 
In Norway, a substantial proportion of 2023
 
capital expenditures will be spent on ongoing development projects such as the Johan
Castberg and the Breidablikk and fields with final investment decisions where plans for
 
development and operation (PDOs) have been
submitted, such as Munin (formerly Krafla), Halten
 
Øst and Irpa. In addition, capital expenditures will be spent on various extensions,
modifications and improvements on currently producing fields.
 
Internationally, we estimate that a substantial proportion of 2023 capital expenditures will be spent on ongoing and planned
development projects such as the Bacalhau field in Brazil and offshore and non-operated onshore activity in
 
the USA.
 
Within renewable energy, capital expenditure in 2023
 
is expected to be spent mainly on offshore wind projects and on the acquisition
of the solar developer BeGreen announced in November 2022.
 
88
 
Equinor, Annual Report on Form 20-F 2022
 
Equinor finances its capital expenditures both internally and externally. For more information, see financial debt and liquidity
management in the section 2.2 High value.
 
Equinor has committed to certain investments in the future. A large part of the capital expenditure
 
for 2023 is committed. The further
into the future, the more flexibility we will have to revise expenditures. This flexibility is partially
 
dependent on the expenditure joint
venture partners agree to commit to. For further information, see note 26 Other commitments, contingent liabilities
 
and contingent
assets to the Consolidated financial statements.
Equinor may alter the amount, timing or segmental or project allocation of capital expenditures
 
in anticipation of, or as a result of
several
 
factors outside our control.
Return on average capital employed (ROACE)
*
The return on average capital employed (ROACE)* was 55.2% in 2022, compared to 22.7% in 2021. The
 
change from 2021 was
mainly due to the increase in adjusted earnings* after tax.
Relative ROACE
*
 
(peer group rank)
On relative ROACE*
 
Equinor was ranked 1
st
 
in the peer group, which is a position in the first quartile.
exhibit154p89i0
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
exhibit154p89i1
Equinor, Annual Report on Form 20-F 2022
 
89
(in USD million, unless stated otherwise)
 
For the year ended 31 December
2022
2021
2020
2019
2018
Share information
1)
Diluted earnings per share (in USD)
9.03
2.63
(1.69)
0.55
2.27
Share price at OSE (Norway) on 31 December (in
 
NOK)
2)
351.80
235.90
144.95
175.50
183.75
Share price at NYSE (USA) on 31 December
 
(in USD)
35.52
26.33
16.42
19.91
21.17
Dividend paid per share (in USD)
3)
1.68
0.56
0.71
1.01
0.91
Weighted average number of ordinary shares outstanding (in
 
millions)
3,174
3,254
3,269
3,326
3,326
1)
See section 5.3 Shareholder information for a description
 
of how dividends are determined and information
 
on share repurchases.
2)
Last day of trading on Oslo Børs was 30 December
 
in both 2022 and 2021.
3)
See note 20 Shareholders' equity and dividends
 
to the Consolidated Financial Statements.
Relative TSR
Equinor assesses performance against a peer group of 11 European and U.S. companies by relative Total Shareholder Return (TSR).
TSR is the sum of a share’s price growth and dividends for the same period, divided by the share
 
price at the beginning of the period
and is provided by a third-party service provider.
The chart above shows TSR for 2022. Equinor is number six with a TSR of 40% (measured in
 
USD).
The year 2022 was weak for global equity markets but a strong year for oil and gas equities.
 
The strong outperformance for energy
markets in 2022 was primarily caused by Russia’s invasion of Ukraine, leading to a shortfall in European
 
supply, which had a
profound impact on European prices for gas and electricity. This resulted in increased earnings, cash flow and share price for
companies with exposure to European gas markets. No company stood out like Equinor, resulting in very strong relative performance
until early September. In the last months of 2022, Equinor showed weaker relative performance due to a fall in European gas prices.
This was due to warmer than expected European weather, and the fact that European storage was no longer a big concern
 
for the
2022-2023 winter as European countries were able to find alternative supplies and eventually
 
refilled their gas storage.
 
The graph below shows the relative performance of Equinor over the five
years from 2018 until 2022. Over this period, Equinor ranks number 2 with
a TSR of 105%.
Equinor’s peer group consist of the following companies:
 
Aker BP,
 
BP,
 
Chevron, ConocoPhilips, Eni, ExxonMobil, Galp, Ørsted,
Repsol, Shell and TotalEnergies.
90
 
Equinor, Annual Report on Form 20-F 2022
 
 
exhibit154p49i0 exhibit154p49i0 exhibit154p49i0 exhibit154p49i0 exhibit154p49i0
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
91
2.2.3 Value
 
creation for society
TOPIC
DESCRIPTION
IMPACTS TO
NATURE
AND SOCIETY
PRINCIPAL RISK
FACTORS/IMPACT
ON EQUINOR
KPI/
MONITORING
INDICATOR
AMBITION
AND STATUS
Value creation for
society, including
generating revenue,
job opportunities and
economic wellbeing
through procurement
and taxes.
Equinor makes
substantial payments to
governments and can
significantly influence
socio-economic
development where
it operates.
 
Business integrity and
ethical misconduct
 
International politics and
 
geopolitical change
 
Joint arrangements and
contractors
 
Ownership and action by
the Norwegian State
Payments to
goverments
(billion USD)
Not applicable
Share of
procurement
spend locally (%)
Not applicable
n
 
Ambition met in 2022.
 
n
 
Ambition not met in 2022.
 
n
 
Plan in place, on track to reach longer-term ambition.
 
n
 
Plan in place, not on track to reach longer-term
 
ambition.
Text in bold:
Key performance indicator.
Contextual introduction
Delivering value to society at large and to our host communities is fundamental to the success
 
of our ongoing business activities and
the energy transition. The turbulent times of 2022 have reinforced our belief in our long-standing
 
purpose and the importance of the
value we bring to people and society, being a reliable provider of energy to our customers while continuing to take vital steps in our
transition.
 
Energy underpins virtually all current economic activity and is a fundamental human well-being and development
 
component. The jobs
we create, taxes we pay and the economic and social benefits we deliver are material contributions
 
Equinor provides to society at
large and to the communities in which we are present.
 
Alongside our tax contributions, a main lever to deliver value to society is through the procurement of goods
 
and services of
approximately 7,500 direct suppliers and their sub-suppliers. Thriving domestic supply chains are important
 
for regional economic
development and for Equinor as we deliver new projects and invest in long-term infrastructure that
 
will operate for decades. Helping to
develop new supply chains is as important as ensuring that our existing suppliers are transitioning
 
along with us to balance creating
new jobs and the minimising job losses in the value chain and beyond our industry.
 
At the core of our efforts to deliver value to society is openness and collaboration with stakeholders and partners to understand
 
their
needs and expectations and to help find mutual benefits and lasting solutions to common challenges.
Management approach
Host communities and value chain partners are key stakeholders in identifying and delivering societal
 
value.
 
Identification of opportunities starts at the early stages of business development. Local authorities
 
and non-governmental
organisations help us understand the needs and expectations of our host communities.
 
These are key to informing business models
and project strategies that can deliver lasting value to the community and its support of our
 
activities.
 
In addition to tax contributions and procurement spending, we deliver socioeconomic benefits such as
 
voluntary or mandatory social
investments, sponsorships and donations. In 2022, we prioritised our efforts towards education and vocational training,
 
institutional
capacity building, cultural enrichment and support for humanitarian aid. All social investments must
 
comply with internal policies and
requirements as well as local regulations.
We measure our performance towards tax contributions and spend on procurement, social investments, sponsorships
 
and donations.
 
Towards the end of 2022, we launched our Just Transition plan and our commitment to contributing to an energy transition that is just
and inclusive and brings long-term social and economic benefits. See equinor.com for more information about our approach and
priorities, including supporting case studies that exemplify how we deliver value to societies accordingly. As we implement this plan,
we will evolve our performance framework on material topics, including defining relevant ambitions.
Actual and potential adverse impacts related to our business activities are further addressed in other
 
parts of the report, more
specifically in Emissions reductions, Integrity and anti-corruption, Safe and secure operations, Protecting
 
nature, and Tackling
inequality - Human rights.
exhibit154p92i1 exhibit154p92i1 exhibit154p92i0 exhibit154p92i0
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
92
 
Equinor, Annual Report on Form 20-F 2022
 
Performance disclosure
Alongside the provision of reliable energy, we continue creating economic value and societal progress through avenues such as: 
 
 
Revenues for countries through the taxes we pay
 
Economic opportunities for our direct suppliers and sub-suppliers and further revenues for countries through
 
our sourcing of
goods and services
 
 
Job creation, training, skills development, and educational investments and enhancement of opportunities
 
for own workforce
and beyond 
 
Innovation, research and development of technologies
 
Our key numbers:
Economic value created and distributed
Indicators
Boundary
Unit
2022
2021
2020
2019
2018
Tax contribution
Equinor group
USD billion
45.2
9.0
3.1
8.8
9.6
Payment to governments (Total
economic contributions to governments)
Equinor group
USD billion
49.2
11.8
4.5
11.6
13.4
Purchase of goods and services (Total
procurement spend)
Equinor group
USD billion
17.1
15.7
16.1
18.4
17.4
Total share of spend locally
Equinor group
%
89
91
89
85
n/r
Corporate donations spend
Equinor ASA
USD million
7.6
1.6
1.8
0.2
0.8
Total social investments spend (excl.
Norway and Denmark)
Equinor group
USD million
6.3
1.9
1.4
3.1
2.1
Voluntary social investments spend
Equinor group
USD million
0,6
0.4
0.6
2,2
1.1
Mandatory social investments spend
Equinor group
USD million
5.7
1.4
0.8
0.9
1.0
Data and information about employees, apprenticeships and graduates can be found in section 1.9 Our
 
people – To get there.
Together
 
.
Enabling societal progress through tax contributions
Paying the right tax where value is created is central to Equinor’s commitment
 
to contributing to progress for societies. In 2022, the
Equinor group paid USD 45 billion in corporate income taxes and USD 4 billion in royalty
 
payments and fees to local and national
governments, including host entitlement. USD 44 billion was paid in Norway, where Equinor has the largest share of its operations
and earnings.
 
The full Payments to governments report for 2022 pursuant to the Norwegian Accounting Act
 
§3-3d and the Norwegian Security
Trading Act §5-5a can be found at our website: equinor.com/reports. We published our second tax contribution report in October
2022, which provides further insight into our approach to tax and explains why and where we
 
pay the taxes we pay.
 
Procurement and ripple effects
 
Enabling local value creation is integrated into how we plan and operate our activities across all
 
parts of our strategy. A significant
contribution to society in terms of monetary value is our purchase of goods and services,
 
totalling approx. USD 17.1 billion in 2022.
Continued sourcing from key suppliers enables them to make long-term plans and investments in
 
securing and creating jobs,
developing new skills and technology and investing in their own supply chains.
 
In Norway, according to a report by Bodø Science Park, we procured goods and services for our operations from over 1,800 suppliers
in 152 Norwegian municipalities in 2021, totalling NOK 77 billion. 90% of all deliveries were by Norwegian
 
suppliers, demonstrating
their capacity, competence and competitiveness.
 
In the UK, our upcoming project Rosebank, according to a socioeconomic study by Wood Mackenzie and Vår Energi, if
 
sanctioned, is
estimated to create GBP 8.1 billion of direct investment, of which GBP 6.3 billion is likely to be invested
 
in UK-based businesses. Over
the 25 years lifetime of the field, Rosebank is forecast to generate a total of GBP 24.1 billion of gross
 
value add (GVA), comprised of
direct, indirect and induced economic impacts.
 
Enabling local opportunities in offshore wind projects
 
Specifically related to floating wind, Equinor has developed a set of design principles and a toolbox
 
to help select solutions that are
both cost-effective and provide opportunities for the local supply chain. Water depths, capabilities of local harbours, and the
competence and capacity of the local supply chain are some of the main drivers when we consider
 
the technology of choice.
 
In Norway,
 
the local supply chain has been awarded over 50% of Hywind Tampen's contract value by being competitive in the chosen
technologies. This contributes to job creation and local economic value and builds know-how for future industrial
 
projects.
 
Equinor, Annual Report on Form 20-F 2022
 
93
In the UK, the Dogger bank offshore wind farm, which will be the world's largest fixed-bottom offshore wind farm has facilitated
 
local
investments, local jobs, contractors, and skills development. During 2022, Equinor led six supply
 
chain workshops to prepare local
suppliers for future tenders and collaborating around skills and innovation. Equinor entered into
 
a number of strategic collaborations in
North-East England including with the Offshore Renewable Energy Catapult, a UK-wide initiative for innovation in
 
renewable energy.
 
Social investments
 
In 2022, we spent around USD 6.3 million on social investments internationally, the majority in which were contractual obligations. The
investments were often targeted towards underprivileged groups and focused on STEM education
 
and vocational training and skills
building to improve employability,
 
as well as healthcare and economic empowerment for women. In 2022, material contributions
included support to infrastructure development in Argentina, and support to local capacity building
 
and innovation through our offshore
wind projects, Empire Wind and Beacon Wind, in the US. An overview of Equinor’s
 
social investments in 2022 is presented in our
ESG data hub.
Supporting humanitarian efforts in a turbulent year
With 2022 marked by Russia’s invasion of Ukraine and a growing humanitarian crisis in its wake, Equinor
 
donated a total of USD 5
million to humanitarian organisations supporting the people in and refugees from Ukraine, as well
 
as organisations working to alleviate
the hunger crisis on the Horn of Africa, that was exacerbated by the war in Ukraine.
In Poland, we supported joint industry initiatives to provide technical assistance and technical
 
equipment to Ukrainian organisations.
We also provided financial aid to support refugees that will remain in the country for a longer period through
 
partnering with local
NGOs, including those cooperating with UN bodies, like the Polish Centre for International
 
Aid and United Nations Global Compact
Poland.
Performance evaluation
Overall, our performance on value creation for society was geared towards ensuring crucial
 
energy production and supply, and
providing significant tax contributions, employment and procurement spending. Alongside these, we
 
extended humanitarian aid to
support direct and indirect victims of the war in Ukraine and continued our local community engagement
 
in the countries of our
operations.
Looking ahead, we will pursue opportunities to further strengthen our activities, performance and
 
disclosures, notably as a part of our
just transition plan.
 
 
exhibit154p49i0 exhibit154p49i0 exhibit154p49i0 exhibit154p49i0
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
94
 
Equinor, Annual Report on Form 20-F 2022
 
2.2.4 Integrity and anti-corruption
TOPIC
DESCRIPTION
IMPACTS TO
NATURE
AND SOCIETY
PRINCIPAL RISK
FACTORS/IMPACT
ON EQUINOR
KPI/
MONITORING
INDICATOR
AMBITION
AND STATUS
Preventing corruption
and ensuring ethical
business culture is
embedded across
the company through
our values, Code of
Conduct and
compliance
programmes.
Corruption undermines
legal business activities,
distorts competition,
ruins reputations and
exposes companies
and individuals to civil
and criminal penalties.
 
Business integrity and
ethical misconduct
 
Joint arrangements and
contractors
 
Policies and legislation
 
Supervisions, regulatory
reviews and reporting
Confirmed
corruption cases
(number of)
0 (2022)
n
Employees who
signed-off the Code
of Conduct (%)
≥95% (2022)
n
n
 
Ambition met in 2022.
 
n
 
Ambition not met in 2022.
 
n
 
Plan in place, on track to reach longer-term ambition.
 
n
 
Plan in place, not on track to reach longer-term
 
ambition.
Text in bold:
Key performance indicator.
Contextual information
Equinor is a global company, and we are present in parts of the world where there is a high risk of corruption. We believe that an
ethical business culture is the cornerstone of a sustainable company, and we continued our work on ethics and compliance
throughout 2022. Our commitment to conduct business in an ethical, socially responsible and transparent
 
manner remained constant,
irrespective of the impact of the the European security situation.
Equinor has a zero-tolerance policy towards all forms of corruption. This is embedded across the company
 
through our values, Code
of Conduct and compliance programmes.
 
Management approach
Code of Conduct
 
The Equinor Code of Conduct sets out our commitment and requirements for how we do business.
 
It applies to our employees, board
members and hired personnel who, each year, are required to confirm that they understand and will comply with the Code of Conduct
and take an online test to certify as competent. We expect our suppliers to act in a way that is consistent with
 
our Code of Conduct
and we engage with them to help them understand our ethical requirements and
 
how we do business. If our expectations are not met,
we take appropriate action.
Anti-corruption
 
Our Code of Conduct explicitly prohibits engaging in bribery and corruption in any form. Equinor’s
 
anti-corruption compliance
programme summarises the standards, requirements and procedures implemented to comply with applicable laws
 
and regulations
and maintain our high ethical standards. The programme lays down the foundation for ensuring
 
that anti-bribery and corruption risks
are identified, concerns are reported, and measures are taken to mitigate risk in
 
all parts of the organisation. We have a global
network of compliance officers who support the business in identifying and handling business integrity risks and
 
ensure that ethical
and anti-corruption considerations are integrated into our activities no matter where they
 
take place. Equinor provides regular training
across the organisation to build awareness and understanding of the anti-corruption compliance programme.
 
Competition and antitrust compliance
 
Equinor’s Code of Conduct also addresses the requirement to comply with applicable
 
competition and antitrust laws. Our competition
and antitrust programme consists of governing documents and manuals, and training of employees in high-risk positions,
 
as well as
regular risk assessments and assurance activities.
 
Reporting and handling of concerns
 
The Code of Conduct imposes a duty to report possible violations of the Code or other incidents
 
of unethical conduct. We require
leaders to take their control responsibilities seriously to prevent, detect and respond to ethical issues. Employees
 
are encouraged to
discuss concerns with their line manager or the line manager’s superior, or use available internal channels established to provide
support. Concerns may also be reported through our Ethics Helpline which allows for
 
anonymous reporting and is open to employees,
business partners and the general public. Equinor has a strict non-retaliation policy.
Roles and responsibilities
The legal business ethics and compliance function is headed by the chief ethics and compliance
 
officer (CECO), who reports to the
executive vice president legal and compliance. The CECO is also able to report matters directly
 
to the CEO, the BoD, the audit
committee (BAC) and the safety, sustainability, ethics committee (SSEC)
.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
95
Collaboration and stakeholder engagement
At Equinor, we believe in the value of collective action to actively promote anti-corruption and revenue transparency. We have long
standing relationships with the UN Global Compact, the World Economic Forum’s Partnering Against Corruption Initiative
 
(PACI) and
Transparency International (TI). In 2022, as a long-standing supporter of the Extractive Industries Transparency Initiative (EITI), we
continued to participate actively in the EITI multi-stakeholder process with the clear objective of
 
strengthening revenue transparency
and good governance in the sector.
Operational targets
Employees having signed the Code of Conduct: 95%
We have a target of zero confirmed incidents of corruption which could lead to corporate criminal liability.
Key initiatives in 2022
KPIs/monitoring indicators and ambitions
The Code of Conduct was updated in 2022, updating several sections and, in particular, those related to communities and
environment.
 
Our training efforts included general and targeted training and awareness sessions and we delivered an increased number
 
of training
activities. Ethics and integrity-related leadership performance goals were made available in 2022,
 
and general leadership training
programmes
 
were updated to explicitly cover ethics and integrity.
Delivering mandatory and voluntary social investments is one of our tools to contribute towards
 
tackling societal challenges. However,
if not done the right way, social investments can expose Equinor to significant business integrity and reputational risks. To reduce this
risk, our requirements and guidance on management of social investments was strengthened in response
 
to changing business needs
and identified challenges.
Performance disclosure
Ethics Helpline
Indicator
Boundary
Unit
2022
2021
2020
2019
2018
Cases and inquiries to the Ethics
Helpline
Public
number
192
160
183
194
182
Confirmed corruption cases
Public
number
0
0
n/r
n/r
n/r
Ethics and compliance training
Indicator
Boundary
Unit
2022
2021
2020
2019
2018
People completing Code of conduct
training and sign-off (Employees)
Equinor group
%
95
84
87
93
83
exhibit154p96i0
96
 
Equinor, Annual Report on Form 20-F 2022
 
Equinor, Annual Report on Form 20-F 2022
 
97
Performance evaluation
The number of cases received through the Ethics Helpline was 192 in 2022, of which 126
 
were reports of concerns. This was an
increase from 2021. The cases included 60 reported concerns relating to harassment, discrimination
 
and other conduct affecting the
working environment. We experienced a decrease in the number of cases related to our suppliers.
The Code of Conduct yearly sign-off is a mandatory competence requirement for all employees in the company. By following up on
the sign-off rates for each business area we were able to monitor the trends closely and saw a significant improvement
 
compared to
2021.
 
Looking ahead, we maintain our commitment to ethical, socially responsible and transparent business
 
conduct. We will continue to
strengthen our risk-based compliance programmes and monitor their effectiveness.
 
98
 
Equinor, Annual Report on Form 20-F 2022
 
2.3 Low carbon
The need for rapid emission reductions and systemic transformation toward net zero
Urgency of the climate challenge
The Paris Agreement calls for rapid emission reductions in accordance with the best available science to
 
achieve a balance between
manmade emissions and sinks of greenhouse gases in the second half of this century. Since the signing of the Paris agreement, the
scientific and physical evidence of climate change has become ever more apparent. In order to meet the
 
goals of the Paris
Agreement, the world’s energy systems will need to undergo a transformation in the coming years to
 
decarbonise. According to the
Intergovernmental Panel on Climate Change’s sixth assessment report, “reducing GHG emissions across the full energy
 
sector
requires major transitions, including a substantial reduction in overall fossil fuel use, the deployment of low-emission
 
energy sources,
switching to alternative energy carriers, and energy efficiency and conservation”.
 
The International Energy Agency (IEA) estimates that clean energy investment must rise above
 
USD 4 trillion by 2030 for the world to
be on track to meet its Net Zero Emissions by 2030 scenario
6
.
 
Companies, customers, governments and society at large will all have
to collaborate, innovate and adapt in new ways to ensure a sustainable future. It will require the
 
development of new technologies,
new value chains, and new ways of working, as well as firm leadership from policymakers. It will also require continuity
 
and the
provision of stable, reliable and affordable energy that the global economy depends on.
Our response
Equinor is committed to long-term value creation in support of the goals of the Paris
 
Agreement. We aim to be a leading company in
the energy transition and have set an ambition to reach net zero by 2050. We realise that this will
 
be a journey that will require an
evolution of the way energy is produced and consumed globally.
 
As an industrial company focused on the production and delivery of oil, gas, electricity and low-carbon
 
products and services, our
business has both direct and indirect negative impacts. Our operations generate significant greenhouse gas
 
emissions (in 2022, for
example, we emitted 11.4 million tonnes of carbon dioxide equivalent (CO
2
e) from our own operations).
 
And, of course, the emissions
associated with the use of the products we sell are many times higher than those from our direct
 
operations, equivalent to 243 million
tonnes of CO
2
e in 2022.
We have already developed an upstream portfolio that is one of the most carbon efficient in the industry. Our ambition to reduce net
group-wide operated scope 1 and 2 emissions by 50% by 2030, shows that we are focused
 
on medium-term actions consistent with
the goals of the Paris Agreement and a 1.5-degree pathway.
Rapidly reducing our own emissions is necessary, but not sufficient. To be an effective agent of change in the energy transition, we
must help society decarbonise by providing our customers and end-users with energy that has lower – and eventually
 
net-zero –
emissions. To achieve this, we have to apply our experience and competence from oil and gas to new sectors of the energy system.
We have built a robust offshore wind portfolio and aim to further strengthen our leading position in floating offshore wind. We are
shaping the low carbon industry, leveraging our advantaged industrial starting point on the Norwegian continental shelf (NCS) and
proximity to the European market.
 
Equinor’s 2022 Energy Transition Plan laid out our strategy for delivering on our ambition to become a net-zero company
 
by 2050,
including emissions from production and final consumption of the energy we produce. In addition
 
to the main corporate
decarbonisation and transition ambitions, the plan included a series of short-term industrial project milestones
 
that demonstrated our
concrete commitment to delivering our transition strategy. A summary of progress against the Energy Transition Plan can be found in
the introductory sections of this report and more detail on our net zero pathway and emissions
 
reductions is provided below.
 
Risk management
To deliver on our transition strategy we have put in place a framework for climate-related risk management that is informed by the
concept of double materiality. Equinor assesses climate risk from two perspectives: transition risk, which assesses the financial
robustness of the company’s business model and portfolio in various decarbonisation scenarios; and physical climate
 
risk, which
assesses the vulnerability of our assets to climate-related perils in different warming scenarios. A full description of
 
how we integrate
climate considerations into our investment and valuation criteria, and details of our CO
₂
 
price forecasts is published in presented in
section 2.2.2 Profitable portfolio.
 
To assess and manage climate-related risks we also use scenario and sensitivity analysis, including
net present value (NPV) stress tests against all relevant scenarios published by the IEA. Details
 
of our stress testing and scenario
analysis are published in section 2.2.2 Profitable portfolio. For physical climate risk, we map the exposure
 
of our global asset portfolio
against a range of climate-related perils and scenarios, including heat, flood, fire, and wind. The
 
results of the 2022 mapping can be
seen in section 2.2.2 Profitable portfolio.
6
World Energy Outlook, November 2022
Equinor, Annual Report on Form 20-F 2022
 
99
Equinor aligns its climate-related disclosures with the recommendations of the Task Force on Climate related Financial Disclosures
(TCFD) and we include explicit reference to the TCFD recommendations in section 5.6.
Using our voice
Our advocacy and policy engagement is also conducted in line with the objectives of the Paris
 
Agreement. Equinor promotes policies
supporting the goals of the Paris Agreement and forceful actions to accelerate the energy transition.
 
We also actively work to ensure
that the policy positions and advocacy of our membership organisations is supportive of and aligned
 
with the objectives Paris
Agreement. To ensure transparency,
 
we conduct and publish an annual review of industry association and membership
 
organisations
showing any areas of potential misalignment. Our climate policy positions and our expectations of our membership
 
associations are
available on Equinor.com. We engage with a wide range of external independent benchmarking and assessment organisations,
including Climate Action 100+, CDP, InfluenceMap and others, in an effort to be a proactive stakeholder in the development of
effective frameworks for assessing corporate performance in the energy transition.
 
exhibit154p100i0 exhibit154p100i1 exhibit154p100i1 exhibit154p100i1 exhibit154p100i0 exhibit154p100i1 exhibit154p100i0
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
100
 
Equinor, Annual Report on Form 20-F 2022
 
2.3.1 Net zero pathway
TOPIC
DESCRIPTION
IMPACTS TO
NATURE
AND SOCIETY
PRINCIPAL RISK
FACTORS/IMPACT
ON EQUINOR
KPI/
MONITORING
INDICATOR
AMBITION
AND STATUS
Achieving net-zero
greenhouse
gas emissions by
2050, including
emissions from
the use of our
products
Equinor has
significant scope
1, 2 and 3 GHG
emissions
(11.4 + 243 million
tonnes CO
₂
e).
 
Climate change and
transition to a lower
carbon economy
 
Competition and
technological innovation
 
International politics and
geopolitical change
 
Policies and legislation
 
Prices and markets
 
Ownership and action
by the Norwegian State
 
Workforce and
organisation
Net carbon
intensity
(gCO
₂
e/MJ)
-20% (2019 -> 2030)
-40% (2019 -> 2035)
n
Renewable energy
installed capacity
(GW)
12-16 installed (2030)
n
Annual gross
CAPEX* to
Renewables
and low carbon
>30% (2025)
>50% (2030)
n
n
 
Ambition met in 2022.
 
n
 
Ambition not met in 2022.
 
n
 
Plan in place, on track to reach longer-term ambition.
 
n
 
Plan in place, not on track to reach longer-term
 
ambition.
Text in bold:
Key performance indicator.
Investing in a broad energy portfolio to accelerate systemic transformation
To meet the climate challenge while also addressing the need for energy, Equinor has developed a metric that shows how we are
progressing towards our own net-zero ambition while simultaneously investing in the transformation
 
of the energy system that will be
necessary to realise the goals of the Paris Agreement. The Net Carbon Intensity (NCI) metric
 
tracks our net emissions, including
scope 3 emissions from the use of our products, in relation to our total energy production from oil,
 
gas, electricity, and hydrogen.
Using a combination of all of the options available to us as a broad energy company, our NCI metric shows how we will deliver energy
with lower emissions over time, helping our customers in their efforts to deliver emission reductions. Our ambition is
 
to reduce our NCI
of 67.8g CO
₂
e/MJ in 2019 by 20% by 2030 and by 40% by 2035. By 2050, we aim to bring the
 
NCI down by 100% - to net zero.
Equinor’s interim NCI ambitions show reductions by 2030 and 2035 greater than those
 
implied by the IEA’s Announced Pledges
Scenario (APS), which assumes that all climate commitments made by governments around the
 
world as of COP26, including
Nationally Determined Contributions (NDCs) and longer-term net-zero targets, will be met in full and on time.
Our strategy for achieving net zero has been informed by engagement with a wide range of stakeholders,
 
including shareholder and
shareholder groups, government, non-governmental organisations, academia, and civil society.
 
In addition to the products and services we provide to our customers, we recognise that we
 
have the potential to have a positive
impact on global emissions reduction through engagement with our suppliers. As a major
 
consumer of goods and services, Equinor
has the opportunity to drive emissions reductions among its suppliers and sub-suppliers. Our Energy
 
transition plan included a
commitment to “work with our suppliers and customers, host governments, and civil society to develop
 
the business models, policies
and frameworks to enable the world to achieve net zero by 2050”.
Management approach
Equinor is applying its competitive advantage to create value in new areas of the energy
 
system and to deliver on our net zero
ambition. We have an ambition to allocate more than 50% of our gross capital expenditure to renewables and low-carbon
 
solutions by
2030. A central element in this effort is our ambition to become a leading global player in offshore wind. We will accelerate growth in
renewables to strengthen our competitive position and achieve the economies of scale necessary
 
to improve returns. To build a
competitive wind portfolio, we are applying our experience in technology, innovation and project delivery and building new
competence and capacity to support the transition. We have an ambition to have a total of 12-16 GW of installed
 
equity-based
renewable capacity
7
by 2030.
To complete our development as a broad energy company,
 
we are building a platform for growth in low carbon solutions with a focus
on hydrogen and CCS. This is a natural next step for Equinor: a way for us to decarbonise
 
our supplies of energy and to help
industrial end-users realise their climate ambitions. Building on our strong position in industrial
 
value chains in Europe, we are
applying our technical and engineering competence to bring low-carbon products and services to the market.
 
We are developing a
broad funnel of options to be at the forefront of maturing these decarbonisation markets
 
over the next ten years. We have established
early positioning in CCS licences and high-impact hydrogen projects in Northwest Europe, working with
 
commercial partners and
7
Installed capacity, including capacity from financial investment
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
101
governments to create new value chains.
 
We have an ambition of developing a CO
₂
 
transport and storage capacity of 5-10 million
tonnes by 2030 and 15-30 million tonnes by 2035.
Our success in achieving our net zero ambition will require collaboration with partners, customers,
 
suppliers, and host governments on
the necessary actions to accelerate the energy transition. Such collaboration takes the form
 
of engagement and advocacy on policy
issues; strategic partnerships with companies across the energy value chain; dialogue and commercial
 
agreement with customers;
consultation and investment in host communities; engagement with suppliers and sub-suppliers; and participation
 
in initiatives with
academia, NGOs,
 
and other stakeholders.
Success also requires an internal governance and performance framework that is informed by
 
our transition ambitions. Equinor’s
remuneration framework contributes to the business strategy, long-term interests and sustainability of the company. In order to better
reflect Equinor’s strategy and the energy transition, the instructions for
 
the BoD compensation and executive development committee
were updated in 2020 to include climate and energy transition-related goals as
 
part of the remuneration policies. The CEO, his direct
reports and Equinor’s wider leadership are assessed based on results within a
 
broad range of topics, including safety, security and
sustainability. The ability of executive leaders to be role models and drive the energy transition forward forms part of the holistic
performance evaluation.
Performance disclosure
Indicators
Boundary
Unit
2022
2021
2020
2019
2018
2017
2016
Energy production
Oil and gas production
Operational
control
million barrels of oil
equivalent (mmboe)
1,129
1,115
1,10
6
1,055
1,077
1,09
9
1,03
0
Oil and gas production
Equity basis
million barrels of oil
equivalent (mmboe)
744
759
758
757
770
759
723
Gas to power
Equity basis
GWh
1012
0
0
0
0
0
0
Renewable energy
delivered to grid
Equity basis
GWh
1,641
1,562
1,66
2
1,754
1,251
830
423
Renewable energy
generated for use by
Equinor
Equity basis
GWh
8
0
0
0
0
0
0
SUM renewable energy
generated
Equity basis
GWh
1,649
1,562
1,66
2
1,754
1,251
830
423
Renewable installed
capacity
Operational
control
GW
0.9
0.7
0.7
0.7
0.8
0.8
0.3
Renewable installed
capacity
Equity basis
GW
0.6
0.5
0.5
0.5
0.6
0.3
0.1
Net carbon intensity
Operational
control/Equity
basis
g CO2e per MJ
energy produced
66.5
67.1
67.8
67.8
n/r
n/r
n/r
Scope 3 GHG emissions
(GHG Protocol cat. 11,
use of sold products)
Equity basis
million tonnes
CO
2
e
243
249
250
247
252
250
239
CO2 emissions captured
and stored per year
Operational
control
million tonnes
0.5
0.3
0.9
1.2
1.3
1.2
1.4
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
102
 
Equinor, Annual Report on Form 20-F 2022
 
Accumulated CO2
emissions captured and
stored
 
Operational
control
million tonnes
26.3
25.8
25.6
24.6
23.4
22.2
20.9
Gross capital expenditure*
in renewables and low
carbon solutions, share of
total
Equinor group
%
14
11
4
2
4
n/r
n/r
Top
 
suppliers, with near-
term emissions reductions
target, absolute or
intensity basis, within
2030
Equinor group
%
65
n/r
n/r
n/r
n/r
n/r
n/r
Investing in the future energy system
To deliver on our medium-term ambitions on the route to net zero, we are positioning ourselves through project execution, organic
business opportunities, strategic business development and through the establishment of commercial
 
agreements and investments in
low-carbon value chains. In 2022 we increased our share of gross capital expenditure* to
 
renewables and low carbon solutions to
14%, up from 11% in 2021. In our renewables business, we demonstrated real progress in 2022 on both project execution and on
building the portfolio pipeline. In addition to laying the first foundations at the Dogger Bank offshore wind
 
farm in the UK and
completion of the Stępień solar project in Poland, we put in place further
 
building blocks for our renewables strategy.
 
Equinor’s
selection as a provisional winner of a lease area on the Outer continental shelf off California provides us with
 
a platform to deliver on
our goal of becoming an offshore wind major in one of the world’s most attractive growth regions for floating offshore wind, while the
acquisition of BeGreen, a Danish solar developer with a strong project pipeline enables will
 
enable us to deliver on our goal of
becoming a market-driven power producer. For our Low Carbon Solutions business 2022 was a year of continued progress
 
in
developing the value chains that will enable hydrogen and CCS to be key enablers in the
 
energy transition. Commercial agreements
and partnerships with key European peers and counterparties – in particular the world’s first cross-border CO
2
 
transportation between
the Northern Lights partnership and fertiliser company Yara – show that we are progressing the business models to take forward the
LCS portfolio. Awards of new CO
2
 
storage licenses in Norway and the UK as well as government support for pioneering
 
cluster
projects such as H2H Saltend were key enablers to deliver on our ambition to deliver on our
 
2030 and 2035 ambitions for CCS and
hydrogen.
 
Net Carbon Intensity
Our 1% reduction in net carbon intensity in 2022 compared to 2021 (66.5 down from 67.1) was driven mainly
 
by the relative increase
in the share of gas to oil production in our production portfolio. Despite increasing our share of gross
 
capital expenditure to
renewables and low carbon solutions, the contribution of renewable energy in our portfolio remained
 
relatively unchanged from 2021,
reflecting the long lead times of the capital cycle between investment and commissioning. Similarly, the amount of CO
2
 
that we
transported and stored in 2022 was 0.5 million tonnes. This is higher than in 2021 but lower than
 
the historical 5-year average. The
main reason for the lower CO
2
 
transport and storage levels is the shutdown of the Hammerfest LNG terminal for repairs until June
2022 and the reduced CO
2
 
injection at the Sleipner field. Both renewable output and CO
2
 
storage and transport volumes will increase
in the coming years as projects reach maturity. The reduction in our scope 3 emissions from use of products sold was principally due
to a reduction in our overall equity production volumes. The addition of the Triton CCGT power generation plant did not materially
affect the portfolio-wide NCI.
 
Supply chain decarbonisation
For the first time in 2022, we engaged a systematic evaluation of our supplier base
 
to assess emission reduction plans and strategies.
 
Among those suppliers that account for the majority of Equinor’s procurement
 
spend, 65% were found to have a stated emissions
reduction target on an absolute or intensity basis by 2030. We will continue to work with suppliers
 
and sub-suppliers to increase this
share and to explore tools and ways of working to increase transparency and reduce emissions across our supply
 
chain.
Equinor, Annual Report on Form 20-F 2022
 
103
Performance evaluation
Our performance in 2022 shows that Equinor is building the foundation to deliver on its
 
net zero ambitions. As a leading indicator,
capital allocation is the metric that showed the most progress in 2022 as we increased the
 
share of gross capex* to low and zero
carbon activities. Given the long lead times needed to bring renewable and low-carbon projects
 
onstream, we saw relatively little
progress in the generation from renewable energy sources or the volumes of carbon stored and
 
transported in 2022. Consequently,
there was relatively little change in the company’s overall net carbon intensity. The 2% reduction in NCI from the 2019 baseline is in
line with expectations. As deployment of renewable and CCS accelerates in the coming years, we
 
expect to see greater progress in
NCI reductions, with the majority of progress towards the 20% reduction ambition in 2030 expected
 
in the second half of this decade.
Meeting the 2030 and 2035 NCI ambitions will put us well ahead of society’s progress towards net zero in
 
2050 as outlined in our
Energy transition plan. Equinor’s ability to deliver on its transition ambitions and
 
its net 2050 ambition will continue to be dependent on
enabling policy and regulatory frameworks. The changed energy security situation in Europe
 
has resulted in both positive and
negative drivers for Equinor’s energy transition. Increased demand for oil and,
 
particularly, natural gas raise expectations for
continued hydrocarbon production, while increased policy support for renewables and low-carbon
 
solutions are likely to accelerate
their deployment in both Europe and the US. Mapping of the decarbonisation targets of our strategic suppliers
 
in 2022 represented the
first step in an important effort to increase transparency and focus on emissions in upstream scope 3 emissions; this will
 
be a
continued area of focus and improvement in 2023.
 
 
exhibit154p49i0 exhibit154p49i0 exhibit154p49i0 exhibit154p49i0 exhibit154p49i0
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
104
 
Equinor, Annual Report on Form 20-F 2022
 
2.3.2 Emissions reductions
TOPIC
DESCRIPTION
IMPACTS TO
NATURE
AND SOCIETY
PRINCIPAL RISK
FACTORS/IMPACT
ON EQUINOR
KPI/
MONITORING
INDICATOR
AMBITION
AND STATUS
Reducing GHG
emissions from
own production
and the use of
our products.
Equinor has significant
scope 1, 2 and 3 GHG
emissions with strong
stakeholder interest in
the transparent and
accurate disclosure of
the carbon intensity
of its energy products
and operating
activities.
 
Climate change and
transition to a lower
carbon economy
 
Competition and
technology innovation
 
Health, safety and
environmental factors
 
Joint arrangements
and technology
innovation
 
Ownership and action
by the Norwegian
State
Absolute GHG
emissions scope 1
and 2 (million
tonnes CO
₂
e)
Net 50% emission
reduction
(2015 -> 2030)
n
Upstream CO
₂
intensity, Scope 1
(kg CO
₂
/boe)
<8 kg/boe (2025)
<6 kg/boe (2030)
n
n
 
Ambition met in 2022.
 
n
 
Ambition not met in 2022.
 
n
 
Plan in place, on track to reach longer-term ambition.
 
n
 
Plan in place, not on track to reach longer-term
 
ambition.
Text in bold:
Key performance indicator.
Supplying reliable oil and gas while halving operated emissions by 2030
Equinor has a proud history as a safe and reliable producer of oil and gas. These energy
 
sources will be needed to power the global
economy for many years to come, including in every independent scenario of what would
 
be needed for a Paris-aligned emissions
trajectory.
 
In addition to being primary sources of energy, oil and gas will also be needed as input to low-carbon fuels for hard-to-
abate sectors such as blue hydrogen and as feedstocks for non-energy applications
 
such as chemicals. The IEA’s analysis from
October 2022 shows that global oil demand is expected to grow in 2023 by 1.7 million barrels
 
per day (mmbpd) to over 101mmbpd.
The IEA’s Net Zero Emissions (NZE) in 2050 scenario, which assumes demand levels consistent with a 1.5-degree trajectory, shows
global oil demand projected to decline at 2.5% per year from 2021 to around 72 million
 
barrels per day in 2030 and 24mmbpd in 2050.
The IEA also sees growing demand for natural gas in the short term, including
 
in it its NZE scenario, which was developed before the
current energy crisis and the attempts to reduce reliance on Russian energy exports. To meet the needs of society, Equinor will
continue to produce oil and gas for the foreseeable future. We aim to excel in operational emissions management,
 
maximising the
efficiency of our infrastructure on the NCS and optimising our high-quality international portfolio. To earn the right to supply the oil and
gas the world demands, we are continuing to improve the industry-leading carbon efficiency of our production.
Our ambition to reduce net group-wide operated emissions by 50% by 2030, shows that we
 
are focused on bringing down our direct
operated emissions in line with reductions necessary for a 1.5-degree pathway. Setting a baseline year that corresponds to the year of
the Paris Agreement enables us to show our early action on emissions reduction and
 
to build on our leadership position throughout
this decade. The ambition, which was announced at our 2022 capital market update, was informed by
 
engagement with a range of
government and non-government stakeholders and will enable us to contribute to national decarbonisation
 
plans in key host
jurisdictions, including Norway’s ambition to reduce its emissions by 55% by 2030 relative to a 1990
 
baseline.
Management approach
Reaching our 50% reduction ambition for operated scope 1 and 2 emissions will require a focused
 
and coordinated effort across the
company on executing and maturing a portfolio of abatement projects, improving energy
 
efficiency of offshore and onshore assets,
developing new technologies, and strengthening resilience in the portfolio, including through consolidation.
 
The abatement projects
primarily include electrification of offshore assets in Norway, mainly by power from shore but also including innovations such as
Hywind Tampen. Projects in the abatement portfolio are selected, developed and executed in close dialogue with authorities and
partners and coordinated through our Norway Energy Hub initiative. In addition to CO
2
 
emissions, we have instituted a renewed focus
on improving our industry-leading performance on methane emissions, with increased
 
emphasis on site-level measurement for
improved quantification and reporting. Carbon offsets will play a minimal role in achieving this ambition, with
 
at least 90% of the
reductions being met through absolute emissions reductions. In the longer term, we see negative
 
emissions solutions and offsets as
making an important contribution to address the climate challenge. We plan to use only carbon credits verified
 
according to high
standards and to disclose information about the type of offsets employed. To ensure quality in our carbon credits, we have established
a set of corporate criteria and principles based on the Oxford Principles for Net Zero Aligned
 
Carbon Offsetting.
To track and incentivise the company’s performance on decarbonisation, we have established a performance indicator that assesses
progress towards the 2030 decarbonisation ambition. The indicator is the first of its kind in
 
Equinor to use a forecast-based
methodology. The indicator tracks the internal forecast for Equinor’s operated GHG emissions in 2030 relative to the reduction level
required to meet the decarbonisation ambition, as well as progress on the portfolio of abatement
 
projects. The indicator was
implemented as an internal corporate KPI in 2023.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
105
In addition to our absolute emissions reduction efforts, we are focused on continuing to improve the industry-leading
 
carbon and
methane efficiency of our profitable upstream portfolio, enabling us to be the resilient and responsible producer
 
of the oil and gas that
the world demands. Performance on the upstream CO
2
 
intensity of the oil and gas portfolio is integrated as a KPI for the BoD and
CEC and is linked renumeration.
 
The same KPI also informs renumeration for business-unit managers as well as an input into the
general bonus for all employees.
Performance disclosure
Indicators
Boundary
Unit
2022
2021
2020
2019
2018
2017
2016
Scope 1 GHG
emissions
Operational
control
million tonnes
CO
2
e
11.4
12.0
13.3
14.7
14.9
15.4
15.4
Scope 1+2 GHG
emissions Norway
Operational
control
million tonnes
CO
2
e
11.0
11.1
11.9
12.4
13.0
13.4
13.4
Scope 1+2 GHG
emissions
Operational
control
million tonnes
CO
2
e
11.4
12.1
13.5
14.9
15.1
15.6
15.7
Scope 2 GHG
emissions (location
based)
Operational
control
million tonnes
CO
2
e
0.1
0.1
0.3
0.2
0.2
0.2
0.3
Scope 2 GHG
emissions (market
based)
Operational
control
million tonnes
CO
2
e
2.5
2.7
2.5
2.9
3.0
2.8
2.6
Scope 3 GHG
emissions (GHG
Protocol cat. 11, use of
sold products)
Equity basis
million tonnes
CO
2
e
243
249
250
247
252
250
239
Business travel GHG
emissions (GHG
Protocol cat. 6)
Operational
control
million tonnes
CO
2
e
0.05
0.01
0.02
0.1
0.1
0.1
0.1
CO
2
 
emissions
Operational
control
million tonnes
11.1
11.6
12.9
14.2
14.4
14.9
14.8
CO
2
 
emissions excl.
flaring
Operational
control
million tonnes
10.4
11.0
11.9
13.0
13.3
13.6
13.4
CO
2
 
emissions from
flaring
Operational
control
million tonnes
0.6
0.7
1.0
1.2
1.2
1.3
1.4
CO2 emissions from
upstream operations
Operational
control
million tonnes
7.6
7.8
8.7
9.6
9.3
9.2
9.7
CO
2
 
emissions from
midstream operations
Operational
control
million tonnes
3.5
3.8
4.2
4.6
5.1
5.6
5.0
CO
2
 
emissions from
other operations
Operational
control
million tonnes
0.02
0.01
0.01
0.01
0.11
0.11
0.04
CO
2
 
emissions
Equity basis
million tonnes
9.1
9.9
10.1
11.5
11.6
12.0
12.7
Upstream CO
2
emissions intensity
Operational
control
kg CO
2
 
per
barrel of oil
equivalent
(boe)
6.9
7.0
8.0
9.5
9.0
8.8
9.8
exhibit154p106i0
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
106
 
Equinor, Annual Report on Form 20-F 2022
 
Upstream CO
2
emissions intensity
Equity basis
kg CO
2
 
per
barrel of oil
equivalent
(boe)
8.5
8.8
9.2
10.7
10.3
10.4
13.0
Maritime CO
2
emissions
Operational
control
million tonnes
CO
2
e
3.8
3.8
4.9
n/r
n/r
n/r
n/r
CH
4
 
emissions
Operational
control
thousand
tonnes
11.2
14.5
17.7
19.0
20.0
19.3
24.2
CH4 intensity
Operational
control
% (m³ CH4
emitted per m³
marketed gas)
0.02
0.02
0.03
0.03
0.03
0.03
0.04
Hydrocarbons flared
Operational
control
thousand
tonnes
203
201
339
414
396
406
443
Upstream flaring
intensity
Operational
control
tonnes of
hydrocarbons
flared per
1000 tonnes
of
hydrocarbon
produced
0.7
0.9
1.7
2.5
2.4
2.1
2.5
Routine flaring (share
of total)
Operational
control
%
3
14
31
27
21
10
14
Operated emissions
In 2022 Equinor was on track to meet its ambitions to halve its operated scope 1 and 2 emissions
 
by 2030. Our total operated scope 1
and 2 GHG emissions for 2022 were 11.4 million tonnes – a 6% decrease from the previous year. Equinor has now achieved a
reduction in absolute operated scope 1 and 2 emissions of around 30% relative to
 
2015.
The main drivers of our reduced scope 1 and 2 emissions were a combination of operational
 
and portfolio measures including:
divestment of our Kalundborg refinery and Bakken asset; modifications and emissions reduction initiatives
 
at our onshore plants at
Mongstad and Kårstø; and a change in strategy at several of our NCS assets from gas injection
 
to gas exports to maximise supplies
to Europe.
In 2022, several abatement projects moved forward, including first power from the Hywind Tampen floating wind facility to our oil and
gas production assets on the NCS and the sanctioning of electrification for Hammerfest LNG and
 
the Njord field. We also saw positive
contributions to our emissions reductions efforts through energy efficiency projects in Norway, which reduced emissions by 200,000
tonnes, and from our international portfolio including the Peregrino gas
import solution, which is expected to avoid around 100,000 tonnes of CO
2
emissions per year in operated emissions.
exhibit154p107i1 exhibit154p107i0
Equinor, Annual Report on Form 20-F 2022
 
107
Figure: Operated scope 1 + scope 2 emissions 2022 vs 2021 with key levers/contributions.
 
Figure: End 2022 forecast for operated emissions to 2030.
 
Equity emissions
Equinor’s equity CO
2
 
emissions in 2022 were 9.1 million tonnes, a decrease from 9.9 in 2021. In 2021 we provided field-based
emissions disclosure of our operated emissions and our partner-operated Norwegian assets. This year, for the first time, we also
provide field-based emissions for our international partner-operated assets in the USA, Canada,
 
and other jurisdictions where we
have approval from partners. We continue to work with our partners to encourage emissions disclosure
 
on a field basis and have
requested consent to publish emissions data from all partners from whom it is required.
 
Upstream intensity
In 2022, Equinor was on track to meet its ambitions with regard to upstream CO
2
 
intensity. The upstream CO
₂
 
intensity of Equinor’s
operated portfolio decreased from 7.0 to 6.9kg CO
₂
/boe, well below the 2025 ambition of 8kg CO
₂
/boe. The main driver for this
change was reduced CO
2
 
levels from operated Norwegian assets which changed their strategy from gas injection
 
to gas export during
2022. There were also significant emissions reductions measures implemented in the upstream
 
portfolio in 2022 (202,000 tonnes
CO
2
), as well as decommissioning of the Veslefrikk field and divestment of the Bakken asset in the United States, both of which had
higher than average upstream emissions intensity. Increased production levels from the electrified asset Martin Linge also have a
positive effect on the intensity.
Figure: Operated CO2 intensity 2022 vs 6-year performance and 2025
target
 
exhibit154p108i0
108
 
Equinor, Annual Report on Form 20-F 2022
 
Methane
Equinor’s 2022 methane intensity for our operated upstream and midstream business remained
 
low at approximately 0.02%. This
represents an industry-leading performance as Equinor’s methane emissions intensity
 
is around 12% of the average of members of
the Oil and Gas Climate Initiative group of companies. Equinor continues to pursue a methane
 
intensity target of near zero by 2030.
Figure: Operated scope 1 + scope 2 methane emissions intensity 2022 vs
6 year historical performance and vs OGCI average.
Flaring
 
Our 2022 upstream flaring intensity was 0.7 tonnes/1000 tonnes of hydrocarbon produced compared with
 
0.9 in 2021. This is
significantly lower than the industry average of 9 (IOGP 2021). Equinor’s low flaring levels
 
are due to continued focus on operational
efficiency and leveraging the well-established gas infrastructure in Norway. The main reason for the reduced flaring levels in 2022 was
decreased flaring from Martin Linge (which experienced start-up flaring in 2021), decommissioning
 
of Veslefrikk B, turnaround
maintenance at Statfjord A, the divestment of the Bakken asset, and the implementation
 
of several emission reduction initiatives.
Performance evaluation
2022 saw positive progress in Equinor’s performance to reduce its absolute operated scope
 
1 and 2 emissions as well as a continued
focus on maintaining industry-leading performance on the carbon and methane intensity
 
of its upstream oil and gas portfolio. While
portfolio changes and production strategy were significant contributors to the reduction in operated
 
emissions and emissions intensity
in 2022, Equinor made progress throughout the year in advancing abatement projects to
 
bring emissions down in line with the 2030
ambition. The newly developed forecast indicator shows that the operated portfolio is currently on
 
track to meet the company’s 50%
reduction ambition by 2030, despite a forecasted increase in emissions in 2025 due to new production
 
projects coming onstream.
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
109
Reporting
 
segment
 
Performance
3.1
3.1.1
3.1.2
3.1.3
3.2
3.3
3.4
Optimised oil and
 
gas
 
E&
P Norway
E&P International
E&P
 
USA
High value growth
 
in
r
enewables
Marketing, midstream and
 
processing (MMP),
 
 
including new market
 
opportunities in low
 
carbon solutions
Other group
 
exhibit154p110i0 exhibit154p110i1
110
 
Equinor, Annual Report on Form 20-F 2022
 
Reporting Segment Performance
Introduction to segmental reporting
Equinor’s business strategy is structured around three pillars: Always safe, High value,
 
and Low carbon:
This means that, to create value as a leader in the energy transition, we are pursuing
 
high
value growth in renewables, and seeking new market opportunities in low-carbon solutions
while, at the same time, optimising our oil and gas portfolio.
In order to effectively manage and execute our strategy, including the ability to measure the progress of the business against its
strategic goals, Equinor’s operations are organised into business areas and followed up through
 
operating segments. The operating
segments directly correspond to the reporting segments – with the exception of the operating
 
segments, Projects, Drilling &
Procurement (PDP), Technology,
 
Digital & Innovation (TDI), and Corporate staff and functions, which are aggregated into the
reporting segment Other.
The Exploration & Production (E&P) segments are responsible for the discovery and appraisal of new resources
 
and commercial
development of the oil and gas portfolios within their respective geographical areas: E&P Norway
 
on the Norwegian continental shelf,
E&P USA in the USA and E&P International worldwide, except for Norway and the
 
USA.
Marketing, Midstream & Processing (MMP) works to maximise value creation in Equinor’s
 
global mid- and downstream positions. The
segment is responsible for the global marketing, trading, processing, and transportation of crude,
 
petroleum products and natural gas,
in addition to power and emissions trading.
 
MMP also leads Equinor’s focus in low-carbon solutions such as carbon capture
 
and
storage (CCS) and other low-carbon energy solutions.
The Renewables (REN) segment is responsible for developing and exploring areas within renewable
 
energy, such as offshore wind,
green hydrogen, storage solutions, and solar power.
Inter-segmental transactions
Internal transactions in oil and gas volumes occur between reporting segments before volumes
 
are sold in the market. Equinor has
established a market-based transfer pricing methodology for the intercompany sale of oil and natural gas that meets
 
the requirements
of applicable laws and regulations. For further information, see section 2.2 High Value for production volumes and prices.
E&P Norway produces oil and natural gas including liquefied natural gas (LNG) which is sold
 
internally to MMP. A large proportion of
the oil and natural gas produced by E&P USA and oil from E&P International is also sold through
 
MMP.
 
The remaining oil and gas
from E&P International and E&P USA is sold directly in the market. In 2022, the average transfer
 
price for natural gas for E&P Norway
was 31.22
USD/MMBtu (compared to 14.43 USD/MMBtu in 2021). For the oil sold from E&P
 
Norway to MMP, the transfer price used
is the applicable market-reflective price minus a cost recovery rate.
Equinor eliminates intercompany sales when combining the results of our reporting segments.
 
Intercompany sales include
transactions recorded in connection with oil and natural gas production in the E&P reporting segments,
 
and in connection with the
Equinor, Annual Report on Form 20-F 2022
 
111
sale, transportation or refining of oil and natural gas production in the MMP reporting segment.
 
Certain types of transportation costs
are reported in the MMP, E&P USA and E&P International reporting segments.
3.1 Optimised oil and gas portfolio
The Norwegian continental shelf (NCS) to deliver value for decades
After more than 50 years of operations Equinor’s equity production from the NCS
 
in 2022 is still high, about 1.387
million boe per day,
and the net operating income from the NCS reached USD 67.6 billion in 2022. Throughout
 
the year, Equinor, together with licence
partners and Norwegian authorities, took several new steps to respond to the rising need for
 
natural gas in Europe and increased gas
production by 8% in 2022.
Going forward, Equinor will continue to add high-value barrels to the portfolio through exploration and increased
 
recovery. A particular
focus will be given to gas. Hence, NCS cash flow and value creation are expected to
 
remain high beyond 2030. In 2022 Equinor was
awarded 26 new production licences and several high-value discoveries were made close to
 
existing infrastructure. Four tie-in projects
reached investment decisions in 2022, adding value and increasing the lifespan of existing infrastructure.
 
An investment decision was
also made for the Munin project. The NCS project portfolio is very robust against potential low oil
 
and gas prices.
The CO
2
 
abatement portfolio is progressing towards the ambition of 50% emissions reduction from
 
operations in Norway by 2030.
Investment decisions were made for both the Njord and Snøhvit future electrification projects. The
 
Oseberg gas capacity and power-
from-shore project got PDO approval in the fourth quarter of 2022. In November the first power was
 
produced from the Hywind
Tampen floating offshore wind farm that will supply the Snorre and the Gullfaks facilities.
Norway energy hub - the plan to transform the NCS into a broad energy province – saw good progress. Equinor
 
together with
Oseberg and Troll licence partners, are in an early phase of developing a floating offshore wind farm intended to provide electric
power to Kollsnes and the Troll and Oseberg fields via an onshore connection point. Blue hydrogen and CCS projects were
significantly strengthened through the award of the Smeaheia CO
2
 
storage licence and agreements on cross-border collaboration.
Transforming the value of international oil and gas
 
Equinor has built its international oil and gas portfolio over the past 30 years, with an equity
 
production of about 0.652 million boe per
day in 2022. In the past few years, Equinor has made significant progress to focus and optimise
 
its international oil and gas portfolio
through divestments and country exits. In the portfolio of assets in production, the focus is on safe
 
and efficient operations, including
measures to reduce carbon emissions. The portfolio of major development projects continues to
 
be further matured and optimised.
In 2022, Equinor completed its exit process from Russia. In Brazil, the Peregrino field and its expansion,
 
Peregrino phase 2, came into
production. The Roncador field started producing additional volumes from an IOR project. The major
 
development project Bacalhau
continued to progress. Meanwhile, in the USA, portfolio optimisation onshore (Northeastern USA) and offshore (US Gulf
 
of Mexico)
performed well. In the Gulf of Mexico, Equinor continues to materially build position with the Vito development,
 
operated by Shell.
Onshore, the significant low-carbon gas positions in the Appalachian Basin continue to generate
 
strong cash flows. Presence in this
region has allowed Equinor to spearhead initiatives that could unlock future CCS and
 
hydrogen opportunities together with key
industrial players.
Proved oil and gas reserves
Proved oil and gas reserves were estimated to be 5,191 million boe at year end 2022, compared
 
to 5,356 million boe at the end of
2021.
exhibit154p112i1 exhibit154p112i0
112
 
Equinor, Annual Report on Form 20-F 2022
 
Changes in proved reserves estimates are most commonly the result of revisions of estimates due
 
to observed production
performance or changes in prices or costs, extensions of proved areas through drilling activities or the inclusion
 
of proved reserves in
new discoveries through the sanctioning of new development projects. These changes are the result of continuous
 
business
processes and can be expected to continue to affect reserves in the future.
Proved reserves can also be added or subtracted through purchases and sales of reserves-in-place
 
or factors outside management
control.
Changes in oil and gas prices can affect the quantities of oil and gas that can be recovered from
 
the accumulations. Higher oil and
gas prices will normally allow more oil and gas to be recovered, while lower prices will normally result
 
in reduced recovery. However,
for fields with production sharing agreements (PSA), higher prices may result in reduced entitlement to
 
produced volumes and lower
prices may result in increased entitlement to produced volumes. These described changes are included
 
in the revisions and improved
recovery (IOR) category in the tables that follows in this report.
The principles for booking proved gas reserves are limited to contracted gas sales or gas with
 
access to a robust gas market.
Equinor prepares its disclosures for oil and gas reserves and certain other supplemental oil and gas disclosures
 
by geographical area,
as required by the US Securities and Exchange Commission (SEC). The geographical areas are
 
defined by country and continent.
These are Norway, Eurasia excluding Norway, Africa, the USA and the Americas excluding USA.
In Norway and other countries where there is a resonable certainty that the authorities will approve the plan for
 
development and
operation (PDO), Equinor recognises reserves as proved undeveloped reserves when the PDO is submitted
 
to the authorities.
Otherwise, reserves are generally booked as proved undeveloped reserves when regulatory approval is received,
 
or when such
approval is imminent. Undrilled well locations in onshore fields in the USA are generally
 
booked as proved undeveloped reserves
when a development plan has been adopted and the well locations are scheduled to be drilled within
 
five years.
Approximately 87% of Equinor’s proved reserves are located in the Organisation
 
of Economic Co-Operation and Development
(OECD) countries. Norway is by far the most important contributor in this category, followed by the USA. Of Equinor's total proved
reserves, 5% are related to PSAs in non-OECD countries such as Angola, Brazil, Azerbaijan, Algeria,
 
Nigeria and Libya. Other proved
non-OECD reserves are related to concession fields in Argentina and Brazil, representing all together
 
7% of Equinor's total proved
reserves.
exhibit154p113i0 exhibit154p113i1
Equinor, Annual Report on Form 20-F 2022
 
113
Changes in proved reserves in 2022
The total volume of proved reserves decreased by 165 million boe in 2022.
Revisions and IOR
Revisions of previously booked reserves, including the effect of improved recovery, increased the proved reserves by
 
net 344 million boe in 2022. The increase is the result of 433 million boe in
 
positive revisions and increased recovery, partially offset
by 89 million boe in negative revisions. Many producing fields had positive revisions due to
 
better performance, new drilling targets
and improved recovery measures, as well as reduced uncertainty due to further drilling and
 
production experience. The positive
revisions also included a direct effect of higher commodity prices, increasing the proved reserves by approximately
 
63 million boe
through increased economic lifetime on several fields. The negative revisions were mainly related to unforeseen
 
events and
operational challenges resulting in reduced production potential on some fields in addition to reduced
 
entitlement volumes from
several fields with PSAs.
Extensions and discoveries
A total of net 278 million boe of new proved reserves were added through extensions and discoveries.
 
Continuous extension of the
proved area in the Appalachian basin together with a record number of submitted PDOs in Norway, of which Munin and Halten Øst
were the largest, are the main contributors in this category.
In addition, this category includes extensions of proved areas through
drilling of new wells in previously undrilled areas at other fields in Norway and in Argentina.
Purchases and sales of reserves-in-place
A total of 36 million boe of new proved reserves in the Statfjord Area, which covers the Norwegian
 
continental shelf (NCS) and UK
continental shelf, were purchased in 2022.
A
total of 128 million boe of sales of reserves-in-place are related to the exit of joint arrangements in Russia
 
in addition to the sale of
the Ekofisk Area and a minority share in the Martin Linge field on the NCS. Equinor
 
has no remaining proved reserves in Russia at
year end 2022.
In the fourth quarter of 2021, Equinor entered into an agreement to divest our interests in the Corrib
 
field in Ireland. Closing is
dependent on governmental approval and is expected to take place in the first quarter
 
of 2023. The sale will result in an estimated
reduction in proved reserves of approximately 11 million boe.
Production
The 2022 entitlement production was 695 million boe, down from 710 million boe in 2021 due to
 
sales, natural decline and operational
challenges.
Development of reserves
 
In 2022, 241 million boe were matured from proved undeveloped to proved developed reserves. Continued
 
drilling in the Appalachian
basin in the USA and on major offshore assets in addition to the production start of Askeladd
 
(Snøhvit), Johan Sverdrup Phase 2 and
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
114
 
Equinor, Annual Report on Form 20-F 2022
 
Peregrino Phase 2 contributed to the major portion of maturation of proved undeveloped
 
to proved developed reserves in 2022.
Smaller volumes are related to individual assets world-wide. The positive revision
 
and improved recovery of proved developed
reserves of 322 million boe is related to increased economic lifetime at some fields, increased
 
activity levels, higher commodity prices
and implementation of improved recovery projects. Finally, 256 million boe was added to proved undeveloped reserves through
extensions and discoveries, the largest of these being Munin and Halten Øst in Norway, in addition to further development in the
Appalachian basin in the USA.
Proved developed and undeveloped reserves
As of 31 December 2022
Oil and
condensate
NGL
Natural gas
Total oil and
gas
 
(mmboe)
(mmboe)
(mmmcf)
(mmboe)
Developed
Norway
731
149
10,294
2,714
Eurasia excluding Norway
35
3
89
53
Africa
107
8
91
131
USA
161
51
1,921
554
Americas excluding USA
216
-
25
220
Total developed proved reserves
1,249
210
12,420
3,672
Undeveloped
Norway
562
60
2,087
994
Eurasia excluding Norway
48
0
5
50
Africa
17
0
-
17
USA
56
9
423
140
Americas excluding USA
316
-
11
318
Total undeveloped proved reserves
999
70
2,526
1,519
Total proved reserves
2,248
280
14,946
5,191
As of 31 December 2022, the total proved undeveloped reserves amounted to 1,519 million boe,
 
65% of which are related to fields in
Norway. The Johan Sverdrup,
 
Snøhvit and Oseberg area fields, which have continuous development activities, together with
 
fields not
yet in production, such as Johan Castberg and Munin, have the largest proved undeveloped reserves
 
in Norway. The largest assets
with proved undeveloped reserves outside Norway, are Bacalhau,
 
Peregrino and Roncador in Brazil, the Appalachian basin, Vito and
Caesar-Tonga in the USA, Mariner in the UK, and ACG in Azerbaijan. All these fields are either producing or will start production
within the next five years.
For fields with proved reserves where production has not yet started, investment
 
decisions have already been sanctioned and
investments in infrastructure and facilities have commenced. There are no material development
 
projects, which would require a
separate future investment decision by management, included in our proved reserves. Some offshore development activities will
 
take
place more than five years from the disclosure date on many fields, but these are mainly
 
related to incremental type of spending, such
as drilling of additional wells from existing facilities, in order to secure continued production.
For projects under development, the Covid-19 pandemic impacted progress due to personnel limitations
 
on offshore as well as
onshore facilities and yards. The
 
pandemic has delayed production start at the Johan Castberg field in Norway. The field was
originally planned to start production in 2022, four years after the field development was
 
sanctioned. The
 
start-up is delayed to 2024.
For our onshore assets, all proved undeveloped reserves are limited to wells that are scheduled to
 
be drilled within five years.
In 2022, Equinor incurred USD 6.9 billion in development costs relating to assets carrying
 
proved reserves, of which USD 5.8 billion
was related to proved undeveloped reserves.
Reserves replacement
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
115
The reserves replacement ratio is defined as the net amount of proved reserves added divided by
 
produced volumes in any given
period.
The 2022 reserves replacement ratio was 76% and the corresponding
 
three-year average was 62%.
The organic reserves replacement ratio, excluding sales and purchases, was 89% in 2022 compared to 127% in
 
2021. The organic
average three-year replacement ratio was 70% at the end of 2022 compared to 68% at the end of 2021.
Reserves replacement ratio
For the year ended 31 December
2022
2021
2020
Annual
76%
113%
(5%)
Three-year-average
62%
61%
95%
Reference to Reserves report
A
separate reserves report is included as Exibit 15.5 to the 2022 annual report on Form 20-F. The Reserves report is covering proved
reserves required by the Securities and Exchange Commission (SEC). The report may also be downloaded
 
from Equinor`s website at
www.equinor.com/reports.
 
 
 
 
 
 
 
exhibit154p116i0
116
 
Equinor, Annual Report on Form 20-F 2022
 
3.1.1 Exploration & Production Norway
The Exploration & Production Norway (E&P Norway) segment covers exploration, field development and
 
operations on the NCS,
which includes the North Sea, the Norwegian Sea and the Barents Sea. E&P
 
Norway aims to ensure safe and efficient operations,
maximising the value potential from the NCS. E&P Norway transforms the NCS using digital
 
and carbon-efficient solutions and is
considering the electrification of several installations.
For 2022, Equinor reports production on the NCS from
45
 
fields operated by Equinor and
nine
 
fields operated by licence partners.
Key events
●
 
In response to the energy crisis in Europe, gas production volumes were boosted by
8%
 
throughout 2022.
●
 
Gas production from the
Snøhvit
 
field in the Barents Sea resumed on 2 June, when the
Hammerfest LNG
 
plant was safely
brought back into operation after having been refurbished following the fire on 28 September
 
2020.
●
 
Equinor and its Troll and Oseberg licence partners announced on 17 June that the development of
Trollvind
, a floating windfarm
in the Troll area of the North Sea, is under consideration.
●
 
First power from
the first turbine at
the
 
Hywind Tampen
 
floating offshore windfarm was delivered on 13 November, and as of
mid-February 2023, seven turbines were on line. Hywind Tampen’s 11
 
floating wind turbines will provide power to the five
Snorre
and
Gullfaks
 
platforms in the North Sea.
●
 
First gas from
 
Askeladd
, the next plateau extender of the
Snøhvit
gas field in the Barents Sea, was achieved on 1 December.
 
●
 
Production from a fifth platform on the
Johan Sverdrup
 
oil and gas field in the North Sea started on 15 December. Johan
Sverdrup’s new processing platform was officially opened by the Minister of Petroleum and Energy on 13 February 2023.
●
 
Production from the
Njord
oil and gas
field in the Norwegian Sea resumed on 27 December, when the refurbished platform A and
storage vessel Bravo were brought on stream. The field had been suspended since 2016 during
 
the platform and vessel upgrade.
●
 
On 10 May, Equinor entered into an agreement to sell to Sval Energi
 
its share in
Ekofisk
 
and a 19% stake in
Martin Linge
. Upon
completion, Equinor holds a 51% operating interest in the Martin Linge field. The transaction was completed
 
on 30 September
and is effective from 1 January 2022.
●
 
On 31 May,
 
Equinor completed the transaction to acquire all of Spirit Energy’s production licences in the
Statfjord
 
area on the
Norwegian and the UK continental shelves. Upon completion, Equinor increased its stake in Statfjord
 
on the NCS and holds a
14.53% stake in
Statfjord unit UK
. Equinor plans to extend Statfjord’s field life to 2040.
●
 
On 1 March 2023, Equinor entered into an agreement to acquire stakes in five oil and gas discoveries
 
in the
Troll, Fram
 
and
Kvitebjørn
areas of the North Sea from Wellesley Petroleum AS. With this, Equinor increases its participating interest in the
discoveries Grosbeak, Toppand, Atlantis, Røver North and Røver South. The transaction is expected to be completed in the first
half of 2023 and will be effective from 1 January 2023.
●
 
In the
Awards for predefined areas
on the NCS, Equinor was awarded
26
 
licences (
12
 
of them as operator) on 18 January for
2021
, and awarded
26
 
licences (
18
 
of them as operator) on 10 January 2023 for
2022
.
The Norwegian Ministry of Petroleum and Energy (MPE) approved the plans for development and
 
operation of:
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
117
Kristin South
 
oil and gas field at Haltenbanken in the Norwegian Sea, to be tied back to
 
the Kristin platform, on 2 February
Partner-operated
Ormen Lange
3
, the third phase of the development of the gas field in the Norwegian Sea,
 
on 8 July.
Oseberg gas phase 2 and power from shore,
the plan for further developing the Oseberg field in the North Sea, on 1
December.
Gina Krog alternative oil export
, where a new pipeline will be laid from the Gina Krog platform to
Sleipner
 
A in the North Sea,
on 15 December.
Halten East
gas field in the Norwegian Sea, to be tied in to the
Åsgard
field, on 13 February 2023.
Together with the licence partners,
 
Equinor submitted plans to the MPE for development and operation of
The
Smørbukk North
 
gas field at Haltenbanken in the Norwegian Sea, a satellite to the
 
Åsgard
field, on 9 November.
The
 
Irpa
 
gas field in the Norwegian Sea,
 
to be tied back to the
Aasta Hansteen
 
platform, on 22 November.
The
Verdande
oil field in the Norwegian Sea, to be tied back to the Norne FPSO, on 6 December.
A partial electrification of the
Njord
oil and gas field in the Norwegian Sea
,
 
to be electrified jointly with
Draugen,
 
on 15
December.
The
 
Munin
(formerly Krafla)
 
oil and gas field in the central North Sea, to be developed in cooperation with
Hugin
(formerly North
of Alvheim),
 
using the groundbreaking concept of unmanned production platform developed by Equinor, on 16 December.
Partner-operated
Fulla
gas field in the central North Sea, to be tied back to the platform planned at
Hugin
 
A, on 16 December.
Partner-operated gas fields
Idun North
 
and
Ørn
in the Norwegian Sea, to be tied back to the
Skarv
 
FPSO, on 16 December.
Partner-operated
Symra
 
oil and gas field in the central North Sea, to be tied back to the
Ivar Aasen
 
platform, on 16 December.
Snøhvit future
, a project to expand gas processing capacity and reduce carbon emissions, constructing a
 
new electric
compressor module on shore and fully electrifying operations at
Hammerfest LNG.
The development will lay the ground for
operations on the Snøhvit field in the Barents Sea towards 2050. The plan was submitted
 
on 20 December.
Partner-operated
Berling
 
gas field in the Norwegian Sea, to be tied back to the
Åsgard
B platform, on 21 December.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
exhibit154p118i0
118
 
Equinor, Annual Report on Form 20-F 2022
 
Major producing fields, field developments and carbon storage licences operated by Equinor
 
and Equinor’s licence
partners
Performance review
E&P Norway - condensed income statement under
 
IFRS
For the year ended 31 December
(in USD million)
2022
2021
Change
Revenues
74,774
38,841
93%
Other income
1,155
546
>100%
Total revenues and other income
75,930
39,386
93%
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
119
Operating, selling, general and administrative expenses
(3,782)
(3,652)
4%
Depreciation, amortisation and net impairment losses
(4,167)
(4,900)
(15%)
Exploration expenses
(366)
(363)
1%
Net operating income/(loss)
67,614
30,471
>100%
For the year ended 31 December
Operational information
2022
2021
Change
E&P Norway entitlement liquid and gas production
 
(mboe/day)
1,387
1,364
2%
Average liquids price (USD/bbl)
97.5
67.6
44%
Average internal gas price (USD/mmbtu)
31.22
14.43
>100%
Operational performance
In response to the energy crisis, Equinor liaised with partners and Norwegian authorities to boost gas exports
 
to Europe through
adjusted production permits, reduced gas injection and augmented energy amount in NGL. A change from gas
 
injection to gas export
from some fields contributed to the
8%
 
increase in the natural gas output throughout 2022, underpinned by safe and dependable
operations.
Equinor decided to maintain high gas production levels from Troll, Oseberg and Heidrun through the summer and postponed
turnarounds at Oseberg from May to September, based on a thorough evaluation of the plants’ technical integrity. This contributed to
refilling European gas storages before the winter, enhancing European security of supply. Equinor collaborated closely with
Norwegian authorities to manage the security situation in 2022 and received support to strengthen
 
physical security both offshore and
onshore.
The 1.7% rise in output from 2021 to 2022 was mainly driven by Martin Linge and Troll phase 3 producing for the
 
full year, Snøhvit
resuming production in June, and increased gas output from Gina Krog, Troll and partner-operated Skarv. This was partially offset by
natural decline. While gas volumes rose by 8%, liquids volumes declined by 6% compared to 2021. For
 
information about the NCS
production, see section 5.5 Production per field. Over time, the volumes lifted and sold will
 
equal entitlement production, but may be
higher or lower in any period due to differences between the capacities and timing of the vessels lifting the volumes
 
and the actual
entitlement production during the period.
Snøhvit’s satellite Askeladd,
 
Njord’s upgraded platform and storage vessel and Johan Sverdrup’s fifth platform were brought into
production in December, adding volumes and prolonging field life. The Hywind Tampen floating wind farm achieved first power in
November, to be fully operational in 2023. Delivering competitive projects, we create long-term value, using standardised and digitised
solutions while maintaining a rigorous quality and cost focus. With the pursuit of ‘the perfect
 
well,’ a modern rig fleet and capitalising
on economies of scale, we attain world-class drilling performance.
To replenish our portfolio with valuable gas volumes for Europe, exploration was conducted near existing infrastructure throughout
2022, resulting in four commercial discoveries. Exploration activity was carried out in 22 wells in
 
2022, compared to 21 wells in 2021.
19 wells were completed with four commercial discoveries in 2022, compared to 18 wells completed
 
with six commercial discoveries
in 2021.
Financial performance
Increased gas production coupled with high realised gas prices drove the unusually high revenues in 2022.
 
Higher gas transfer price
and liquids price increased net operating income and revenues from 2021 to 2022. The increase in
 
revenues was partially offset by
the NOK/USD exchange rate development. Gain on divestment of Ekofisk and a 19% participating
 
interest in Martin Linge increased
other income from 2021 to 2022. In 2021, other income was mainly affected by an insurance settlement related
 
to the Melkøya fire in
2020.
Increased maintenance, operational activities, higher environmental taxes and electricity prices led to
 
increased operating expenses
and selling, general and administrative expenses from 2021 to 2022. New fields also contributed to the
 
increase, which was partially
offset by the NOK/USD exchange rate development.
Increased proved reserves on several fields and decreased depreciation of the asset retirement
 
obligation (ARO) along with the
NOK/USD exchange rate development decreased depreciation, amortisation and net impairment losses from
 
2021 to 2022. The
ramp-up of new fields partially offset the reduction.
Higher drilling cost on expensed wells and a decrease in recapitalisation of previously expensed
 
wells contributed to a minor increase
in exploration expenses from 2021 to 2022. This was partially offset by lower field development costs.
Balance sheet information:
 
The sum of equity accounted investments and non-current segment assets was USD
 
28,513 million for
the year ended 31 December 2022, compared to USD 36,506 million for the year ended
 
31 December 2021.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
exhibit154p120i0 exhibit154p120i1
120
 
Equinor, Annual Report on Form 20-F 2022
 
Fields in production on the NCS
The table below shows E&P Norway's average
 
daily entitlement production for the years ending 31
 
December 2022, 2021 and 2020.
Production increased in 2022 due to Martin Linge
 
producing for the full year, Snøhvit resuming production in June, and
 
increased gas
production from Gina Krog, Troll and Skarv, partially offset by natural decline.
Average daily entitlement production
 
For the year ended 31 December
2022
2021
2020
Oil and NGL
 
Natural gas
Oil and NGL
 
Natural gas
Oil and NGL
 
Natural gas
Area production
mbbl/day
mmcm/day
mboe/day
mbbl/day
mmcm/day
mboe/day
mbbl/day
mmcm/day
mboe/day
Equinor operated fields
 
557
 
 
110
 
 
1,251
 
 
585
 
 
101
 
 
1,223
 
 
570
 
 
96
 
 
1,173
 
Partner operated fields
 
48
 
 
14
 
 
136
 
 
58
 
 
13
 
 
141
 
 
60
 
 
13
 
 
143
 
Total
 
605
 
 
124
 
 
1,387
 
 
643
 
 
115
 
 
1,364
 
 
630
 
 
109
 
 
1,315
 
Main producing fields on the NCS
Fields operated by Equinor
Johan Sverdrup
(Equinor 42.63%)
is a major oil field with associated gas in the North
Sea, developed with five platforms: Two processing platforms, a drilling platform, a riser
platform and a living quarters platform. Crude oil is exported to Mongstad through a 283-
km designated pipeline, and gas is exported to the gas processing facility at Kårstø
through a 156-km pipeline via a subsea connection to the Statpipe pipeline. First oil was
achieved in October 2019 and the fifth Johan Sverdrup platform, a processing platform
connected to the field centre, was
brought on stream on 15 December
2022.
Troll
 
(Equinor 30.58%) in the North
Sea is the largest gas field on the
NCS and a major oil field. The Troll
field regions are connected to the Troll A, B and C platforms. Troll gas is produced
mainly at Troll A, and oil mainly at Troll B and C. Fram, Fram H Nord and Byrding
are tie-ins to Troll C.
Over recent years, new compressors have increased the gas processing capacity:
one compressor was brought on stream at Troll B in September 2018, and one at
Troll C in January 2020. In August 2021, the third phase of the Troll field
development was brought on stream, producing from the Troll West gas cap.
A partial electrification of Troll B and a full electrification of Troll C are underway.
The Troll A platform, brought on stream in 1996, was the first electrified
installation on the NCS.
The
Gullfaks
 
(Equinor 51.00%) oil and gas field in the North Sea is developed
with three platforms. Since production started on Gullfaks in 1986, several satellite
fields have been developed with subsea wells which are remotely controlled from
the Gullfaks A and C platforms. The first power from the Hywind Tampen floating
windfarm was supplied to Gullfaks A in November 2022.
The
Oseberg
 
area (Equinor 49.30%) in the North Sea produces oil and gas. The
development includes the Oseberg field centre, Oseberg C, Oseberg East and
Oseberg South production platforms. Oil and gas from the satellite fields are
transported to the Oseberg field centre for processing and transportation. Oseberg
Vestflanken
 
2 came on stream in October 2018. The wellhead platform was
Norway’s first unmanned platform, remotely controlled from the Oseberg field
Equinor, Annual Report on Form 20-F 2022
 
121
centre. To boost recovery and cut emissions, the installation of two new compressors is underway, and a cable to Kollsnes is
projected to connect to the onshore grid for a partial electrification.
The
Åsgard
 
(Equinor 34.57%) gas and condensate field in the Norwegian Sea is developed with
 
the Åsgard A FPSO for oil, the
Åsgard B semisubmersible floating production platform for gas and condensate, and the Åsgard
 
C storage vessel for oil and
condensate. Åsgard C also provides storage for oil produced at Kristin and Tyrihans. In 2015 Equinor started the world’s first subsea
gas compression train on Åsgard. The Trestakk field is tied back to Åsgard A. The Halten East gas field is
 
being developed in a
subsea solution tied back to Åsgard.
The
Martin Linge
 
(Equinor 51.00%) oil and gas field in the North Sea was brought on stream in
 
June 2021. The field is developed
with an integrated wellhead, production and accommodation platform and a permanently anchored
 
oil storage vessel. The gas is
piped to St Fergus, Scotland, and the oil is shipped in shuttle tankers, after being processed
 
on board the storage vessel. The field is
operated from shore. In 2018, the field development started running on power from shore.
Visund
(Equinor 53.20%, operator) oil and gas field in the North Sea is developed with the Visund
 
A semisubmersible integrated
living quarters, drilling and processing unit, and a subsea installation in the northern part of the field. The
 
Visund North improved oil
recovery development, a subsea solution with two new wells in a new subsea template, was
 
brought on stream in September 2018.
The
Aasta Hansteen
 
(Equinor 51.00%, operator) gas and condensate field in the Norwegian Sea
 
is developed with a floating spar
platform and two subsea templates. With the Snefrid North well drilled from the seabed at
 
a depth of 1,309 metres, the field
development is the deepest ever on the NCS. The Irpa gas field is being developed in a subsea
 
solution tied back to Aasta Hansteen.
The
Tyrihans
 
(Equinor 58.84%, operator) oil and gas field in the Norwegian Sea is developed with
 
five subsea templates tied back to
Kristin.
The
Snøhvit
 
(Equinor 36.79%, operator) gas and condensate field is developed with several subsea
 
templates. Snøhvit was the first
field development in the Barents Sea and is connected to the liquefied natural gas processing
 
facilities at Melkøya near Hammerfest
through a 160-km pipeline. First gas from
Askeladd
, the next plateau extender of Snøhvit,
 
was achieved on 1 December 2022. The
Askeladd development includes two subsea templates, a 42-km tie-back to
Snøhvit
 
and drilling of three gas producers. Operations
resumed at the refurbished Hammerfest LNG plant in June 2022, after having been suspended following
 
the Melkøya fire in
September 2020.
Askeladd West
, a satellite to Snøhvit, is under development.
Fields operated by licence partners
Ormen Lange
(Equinor 25.35%, operated by A/S Norske Shell) is a deepwater gas field in the Norwegian Sea. The
 
well stream is
transported to an onshore processing and export plant at Nyhamna. Gassco became operator of Nyhamna from
 
1 October 2017, with Shell as technical service provider. Two new subsea compressor stations are underway, projected to be tied into
the existing Ormen Lange pipeline.
Skarv
 
(Equinor 36.17%, operated by Aker BP ASA) is an oil and gas field in the Norwegian Sea.
 
The field development includes an
FPSO and five subsea multi-well installations.
Ærfugl
 
(Equinor 30.00%, operated by Aker BP ASA) is a subsea development of the gas and condensate
 
discoveries Ærfugl and
Snadd Outer fields in the Norwegian Sea, near the Skarv field, around 200 km west of Sandnessjøen.
 
The field is tied into the Skarv
FPSO for processing and storage.
Ivar Aasen
 
(Equinor 41.47%,
operated by Aker BP ASA) is an oil and gas field in the North Sea. The
 
development includes a fixed
steel jacket with partial processing and living quarters tied in as a satellite to Edvard Grieg
 
for further processing and export.
Goliat
(Equinor 35.00%, operated by Vår Energi ASA) was the first oil field developed in
 
the Barents Sea. The field consists of subsea
wells tied back to a circular FPSO. The oil is offloaded to shuttle tankers.
Marulk
 
(Equinor 33.00%, operated by Vår Energi ASA) is a gas and condensate field
 
developed as a tie-back to the Norne FPSO.
For information about the NCS production, see section 5.5 Production per field.
Exploration on the NCS
Equinor holds exploration acreage and actively explores for new resources in all three regions on the
 
NCS, the Norwegian Sea, the
North Sea and the Barents Sea. The North Sea and Norwegian Sea continue to be the most
 
important areas for exploration, whereas
the exploration activity in the Barents Sea is expected to decrease and become more
 
focused close to existing infrastructure.
In the
Awards for predefined areas
on the NCS, Equinor was awarded
26
 
licences (
12
 
of them as operator) on 18 January 2022 and
awarded
26
 
licences (
18
 
of them as operator) on 10 January 2023.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
122
 
Equinor, Annual Report on Form 20-F 2022
 
In 2022, Equinor and its partners completed
19
 
exploratory wells and made
4
 
commercial discoveries.
Exploratory wells drilled
1)
 
For the year ended 31
December
2022
2021
2020
North Sea
Equinor operated
6
10
10
Partner operated
3
2
2
Norwegian Sea
Equinor operated
4
2
4
Partner operated
4
0
6
Barents Sea
Equinor operated
2
2
4
Partner operated
0
2
0
Total (gross)
19
18
26
1) Wells completed during the year, including appraisals of
earlier discoveries.
Projects under development
Askeladd West
 
(Equinor 36.79%, operator) is a planned satellite to the
Snøhvit
gas field in the Barents Sea. The project was
sanctioned in April 2021. The projected subsea development is 195 km from the Melkøya
 
plant and will include a subsea template tied
in to
Askeladd
. The project is expected to be ready for first gas in the fourth quarter of 2025.
Breidablikk
(Equinor 39.00%, operator) is an oil field in the North Sea. The MPE approved the plan
 
for development and operation of
the field on 29 June 2021. The field is being developed with a subsea solution tied
 
back to the
Grane
 
platform. After being processed
at Grane, produced oil will be transported to the Sture terminal. Offshore modification work began March 2021,
 
and the first oil
producer was completed in the third quarter of 2022. First oil is planned for first half of 2024.
Gina Krog alternative oil export
(Equinor 58.70%, operator) comprises a new pipeline to be laid from the Gina Krog platform
 
to
Sleipner A in the North Sea to replace the current export using an FSO and tankers.
 
The MPE approved the amended PDO for Gina
Krog on 15 December, and the new 23 km pipeline is expected to be operational in the fourth quarter of 2024.
Halten East
(Equinor 57.70%, operator)
gas fields at Haltenbanken in the Norwegian Sea are being developed in
 
a subsea solution,
to be tied back to the Åsgard B platform. The plan for development and operation was
 
approved on 13 February 2023. The
development is expected to be brought on stream in early 2025.
Hywind Tampen
 
(Equinor 33.28% - Snorre and 51.00% - Gullfaks, operator) is a 94.6 MW floating offshore wind pilot being
developed to provide power from 11 wind turbines to the
Snorre
and
Gullfaks
 
installations in the Tampen area of the North Sea. The
MPE approved the plans for development and operation on 8 April 2020. The 11 wind turbines under installation are based on the
Hywind technology developed by Equinor, and are expected to meet around 35% of the annual power needs of the five offshore
platforms Snorre A, B and C and Gullfaks A and B. Construction started in October
 
2020. The wind farm started generating power
from the first turbine in November 2022, and all turbines are expected to be brought on line in 2023.
Johan Castberg
 
(Equinor 50.00%, operator) develops the three oil discoveries Skrugard, Havis and Drivis,
 
around 240 km northwest
of Hammerfest in the Barents Sea. The MPE approved the plan for development and
 
operation of the field on 28 June 2018. The
development includes an FPSO and a subsea development with 30 wells, ten subsea templates
 
and two satellite structures. The new
FPSO hull sailed from Singapore in February 2022, headed for the Stord yard. In August 2022,
 
the crane vessel
Sleipnir
 
installed the
turret manifold, winch and gantry – the last two modules - onto the FPSO. Covid-19
 
precautionary measures, such as manning
limitations and quarantining, affected progress, and first oil was rescheduled to the fourth quarter of 2024.
Kristin South
(Equinor 54.82%, operator) is a development of the Kristin Q segment and Lavrans discovery in
 
the Norwegian Sea.
The MPE approved the plan for development and operation of the Kristin South oil
 
and gas field on 2 February 2022. The field is
being developed as a subsea solution with two subsea templates tied back to the Kristin platform.
 
Production is scheduled to begin in
2024.
Ormen Lange phase 3
(Equinor 25.35%, operated by A/S Norske Shell) In this third phase of the development
 
of the gas field in the
Norwegian Sea, two new subsea compressor stations will be tied into the existing Ormen Lange
 
pipeline to enhance field recovery.
 
Equinor, Annual Report on Form 20-F 2022
 
123
The MPE approved the PDO on 8 July 2022.
Oseberg gas phase 2 and power from shore
(Equinor 49.30%, operator)
is a development to increase gas production and reduce
carbon emissions from the Oseberg field in the North Sea. The development comprises installation
 
of two new compressors to
increase recovery with low pressure production, and the installation of a 118 km cable to Kollsnes to connect to the onshore power
grid for a partial electrification of the Oseberg field centre and the Oseberg South platform.
 
The MPE approved the plan for
development and operation on 1 December 2022. The project is expected to be completed in
 
2026.
Troll West electrification
 
(Equinor 30.60%, operator) is a development to provide Troll B and C with electric power in a new subsea
high-tension cable from from Kollsnes in Øygarden. T
he MPE
approved the plan for development and operation of the Troll West
electrification on 17 December 2021. In 2022, topside modification work was being conducted at
 
Troll B and C platforms. The Kollsnes
- Troll B static cable was laid in third quarter of 2022. The fabrication of the transformer module at Stord also began in third quarter.
Troll B
 
is planned to be partially electrified by 2024 and
Troll C
is expected to be fully electrified by 2026.
Decommissioning on the NCS
Under the Petroleum Act, the Norwegian government has imposed strict regulations for removal
 
and disposal of offshore oil and gas
installations. The Convention for the Protection of the Marine Environment of the Northeast
 
Atlantic (OSPAR), which Norway has
committed to, gives requirements with respect to how disused offshore oil and gas installations are to be disposed of.
Heimdal
(Equinor 29.40%, operator) is due to cease production in 2023. The Heimdal main platform
 
and Gassco/Gassled’s riser
platform are scheduled to be removed between 2025 and 2027. The platforms will be brought to shore at Eldøyane,
 
Stord, for
dismantling and recycling.
Veslefrikk
 
(Equinor 18.00%, operator) ceased production on 17 February 2022. Plugging of wells
 
started early in 2021 and was
completed in the first quarter of 2022. Veslefrikk B was towed to shore for dismantling and recycling at MARS in Frederikshavn,
Denmark, in summer 2022. Veslefrikk A is scheduled to be removed in 2025/2026 and will be brought to Eldøyane, Stord, for
dismantling and recycling.
For further information about decommissioning, see note 23 Provisions and other liabilities
 
to the Consolidated financial statements.
Climate measures
The electrification of offshore and onshore installations is a prerequisite for Norway reaching its national climate goals under
 
the Paris
agreement. Work is underway to electrify Snorre and Gullfaks with renewable power from Hywind Tampen floating windfarm, and to
electrify Sleipner, Gina Krog, Oseberg field centre, Oseberg South, Troll B and Troll C (fully) with power from shore. Plans to electrify
Snøhvit and Hammerfest LNG and Njord were submitted to the authorities in December. The development of the Trollvind floating
windfarm is being considered.
●
 
Power production from Hywind Tampen floating windfarm began in November. Once all 11
 
turbines are on stream in 2023,
Hywind Tampen is expected to provide around 35% of the power need of the five Snorre and Gullfaks platforms. This is expected
to cut CO
2
 
emissions from the fields by around 200,000 tonnes a year.
For more information about our renewables
 
position including floating windfarms using our Hywind technology, see section 3.2
High-value growth in renewables (REN).
 
●
 
The ongoing electrification of offshore installations with power from shore is expected to cut CO
2
 
emissions from the fields as
follows: Sleipner 150,000 tonnes a year, Gina Krog 320,000 tonnes a year, Oseberg 320,000 tonnes a year and Troll 450,000
tonnes a year. In the plan submitted for Njord, the electrification is expected to cut CO
2
 
emissions by 130,000 tonnes a year.
●
 
At Melkøya, Equinor plans installing electric onshore compressors for Snøhvit and electrifying operations
 
at Hammerfest LNG.
The development will expand gas processing capacity and cut CO
2
 
emissions by around 850,000 tonnes a year.
 
For more information about our activities within marketing, transport and processing of gas and
 
liquids, see section 3.3
Marketing, midstream and processing (MMP), including new market opportunities in low carbon solutions.
●
 
Equinor and its Troll and Oseberg licence partners are considering developing Trollvind, a floating windfarm in the Troll area. If
realised, Trollvind will provide renewable power to the Troll and Oseberg offshore installations and the Kollsnes onshore
processing plant via an onshore connection point.
 
For more information about our renewables position including floating windfarms using our Hywind
 
technology, see section 3.2
High-value growth in renewables (REN).
Carbon capture and storage are to play a major role in the Norwegian climate solution. Northern
 
Lights was in 2019 granted the first
licence on the NCS for CO
2
 
storage, and the development of the infrastructure is well underway. In 2022, Equinor was awarded the
operatorship of Smeaheia licence for CO
2
 
storage on the NCS.
 
●
 
Together with Shell and TotalEnergies,
 
Equinor is developing the Northern Lights infrastructure for transport and storage of CO
₂
in the northern part of the North Sea. A first well was drilled in 2020, confirming that the reservoir
 
rocks are suited for CO
2
storage. A second injection well was completed in November 2022, and Northern Lights is expected to
 
come on stream in 2024.
124
 
Equinor, Annual Report on Form 20-F 2022
 
The project is part of Longship, the Norwegian authorities’ project for full-scale carbon capture, transport
 
and storage in Norway.
●
 
In April 2022, Equinor was awarded the operatorship for developing the CO
2
 
storage Smeaheia in the North Sea.
For more information about our development of CO
2
 
storages and low-carbon solutions, see section 3.3 Marketing, midstream
and processing (MMP), including new market opportunities in low carbon solutions.
exhibit154p125i0
Equinor, Annual Report on Form 20-F 2022
 
125
3.1.2 Exploration & Production International
The Exploration & Production International (E&P International) reporting segment covers exploration,
 
development and production of
oil and gas outside the NCS and the US.
E&P International was present in 13 countries and had production in 11 countries in 2022. E&P International accounted for 16% of
Equinor’s total equity production in 2022, the same level as in 2021.
Equinor continues to shape the international oil and gas portfolio, focusing activity in
 
areas with high value potential, and continues to
optimise its strong set of development projects.
In 2022, Equinor continued to implement measures to deliver on our climate ambitions and worked
 
closely with partners to drive
 
CO
2
and methane reductions in both our operated and non-operated assets.
Key events
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
exhibit154p126i0
126
 
Equinor, Annual Report on Form 20-F 2022
 
●
 
On 28 February, Equinor announced its decision to stop any new investments into
Russia
, and to start the process of exiting
from Equinor’s Russian joint ventures. On 25 May, the exit from all joint ventures was completed in accordance with Norwegian
and EU sanctions, and on 2 September, the exit from Kharyaga
was completed. Following the exit from Kharyaga, Equinor has
no remaining assets or liabilities relating to projects in Russia.
●
 
On 31 May, Equinor completed the transaction to acquire all of Spirit Energy’s production licences in the Statfjord area. Upon
completion Equinor UK Limited obtained
14.53% in
Statfjord Unit
 
and increased its interest in
Barnacle
in the UK from 65.70%
to 100%.
●
 
On 16 July, Equinor resumed production from the
Peregrino
 
field in
Brazil
, which had been shut down since April 2020.
●
 
On 12 August, Equinor together with its partners, signed agreements which will extend
 
the production sharing contract and lease
for OML 128 in
Agbami
 
licence in
Nigeria
 
for
20 more years.
●
 
On 10 October, the new
Peregrino C
 
platform in
Brazil
 
came on stream, extending the field life and reducing CO
2
 
emissions per
barrel.
●
 
On 3 March 2023, Equinor UK Limited announced an agreement to purchase Suncor Energy UK
 
Limited. With this, Equinor will
acquire a non-operated 29.89% interest in the producing
Buzzard
 
oil field and increase its operated interest in the future
development of the
Rosebank
 
oil field from 40% to 80%. The transaction is subject to regulatory approval and is expected
 
to be
completed in mid-2023.
For more information about the transactions included above see note 6 Acquisitions and disposals
 
to the Consolidated financial
statements.
Performance review
E&P International - condensed income statement under
 
IFRS
For the year ended 31 December
(in USD million)
2022
2021
22-21 change
Revenues
7,224
5,346
35%
Net income/(loss) from equity accounted investments
172
214
(20%)
Other income
35
5
>100%
Total revenues and other income
7,431
5,566
34%
Purchases [net of inventory]
(116)
(58)
>100%
Operating, selling, general and administrative expenses
(1,698)
(1,406)
21%
Depreciation, amortisation and net impairment losses
(1,731)
(3,321)
(48%)
Exploration expenses
(638)
(451)
41%
Net operating income/(loss)
3,248
329
>100%
For the year ended 31 December
Operational information
2022
2021
22-21 change
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
127
E&P equity liquid and gas production (mboe/day)
328
342
(4%)
E&P entitlement liquid and gas production (mboe/day)
235
246
(5%)
Production sharing agreements (PSA) effects
94
96
(3%)
Average liquids price (USD/bbl)
92.0
67.6
36%
Operational performance
Equinor’s exit from Russia and a natural decline for several mature fields were
 
the main drivers for the decrease in production in 2022
compared to 2021. This was partially offset by the restart of production at the Peregrino field in Brazil
 
in July 2022 and the start-up of
Peregrino phase 2 in October.
 
The lower effect from production sharing agreements (PSA) in 2022 compared to 2021 was mainly
caused by lower production from several fields with PSAs,
 
partially offset by effects from increased liquids and gas prices.
Financial performance
 
Higher realised liquids and gas prices were the main drivers for the increase in revenues in
 
2022 compared to 2021. This was partially
offset by lower entitlement production. The decrease in net income from equity accounted investments was
 
primarily caused by
Equinor’s exit from Russia, partially offset by increased income from Argentina.
Operations and maintenance expenses increased mainly due to the restart of production
 
at the Peregrino field. Royalties and
production fees increased as result of improved prices and field specific volumes.
 
Depreciation decreased in 2022 compared to 2021 primarily due to effects from an impairment in 2021, lower production
 
from
declining fields, and portfolio changes. This was partially offset by additional investments,
 
and depreciations for the Peregrino field
following the restart of production in 2022.
 
Net impairments related to property, plant, and equipment decreased from USD 1,587 million in 2021 to USD 286 million in 2022. In
2022, the main contributors were impairments related to Equinor’s exit
 
from Russia, partially offset by an impairment reversal of an
asset in the Europe and Asia area mainly caused by optimisation of the production profile
 
and higher prices, supported by a slight
increase in reserves estimates. In 2021, the main contributors were impairments of assets
 
in the Europe and Asia area caused by
reduced reserve estimates.
 
Expensing of previously capitalised well cost and higher expensed drilling costs were the main
 
drivers for the increase in exploration
expenses in 2022 compared to 2021.
Balance sheet information:
 
The sum of equity accounted investments and non-current segment assets was USD
 
16,418 million for
the year ending 31 December 2022, compared to USD 16,839 million for the year ending 31 December
 
2021.
International production
In production sharing agreements (PSAs) and production sharing contracts (PSCs), entitlement production
 
differs from equity
production. Equity production in PSAs and PSCs represent Equinor’s percentage
 
ownership in a particular field, whereas entitlement
production represents Equinor’s share of the volumes distributed to the partners in the
 
field, which is subject to several deductions
including but not limited to royalties and the host government's share of profit oil (see section
 
5.9 Terms and abbreviations).
Equinor's entitlement production outside Norway and the US was 12% of Equinor's total entitlement production
 
in 2022.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
exhibit154p128i0
128
 
Equinor, Annual Report on Form 20-F 2022
 
For further detailed production data see section 5.5 Production per field.
Average daily entitlement production
For the year ended 31 December
2022
2021
2020
Oil and NGL
 
Natural gas
Oil and NGL
 
Natural gas
Oil and NGL
 
Natural gas
Production area
mboe/day
mmcm/day
mboe/day
mboe/day
mmcm/day
mboe/day
mboe/day
mmcm/day
mboe/day
Americas (excluding US)
 
66
 
 
1
 
 
69
 
 
52
 
 
1
 
 
56
 
 
67
 
 
1
 
 
72
 
Africa
 
95
 
 
2
 
 
111
 
 
94
 
 
3
 
 
115
 
 
115
 
 
3
 
 
136
 
Eurasia
 
30
 
 
2
 
 
42
 
 
42
 
 
2
 
 
54
 
 
47
 
 
2
 
 
63
 
Equity accounted
production
 
12
 
 
0
 
 
13
 
 
19
 
 
0
 
 
21
 
 
6
 
 
0
 
 
7
 
Total
 
203
 
 
5
 
 
235
 
 
207
 
 
6
 
 
246
 
 
236
 
 
7
 
 
278
 
Americas (excluding the US)
Argentina
Bandurria Sur
is an onshore block in Argentina’s Neuqu
é
n province in the core area of the prolific Vaca Muerta play. Equinor entered
the licence in 2020.
Brazil
Peregrino
 
is a heavy oil field in the offshore Campos basin and is operated by Equinor. The oil is produced from three wellhead
platforms with drilling capability, processed on the FPSO Peregrino and offloaded to shuttle tankers.
Production from Peregrino started in 2011 but was shut down in April 2020 for unplanned maintenance of the subsea equipment.
Production was resumed in July 2022 following major maintenance, upgrade and repairs on the FPSO
 
to allow a safe restart.
As part of the second phase of the field development, the third wellhead platform, Peregrino
 
C, was brought on stream in October
2022, extending the field life. Peregrino C will import gas and lead to fuel switching
 
on the FPSO, ensuring a significant reduction in
diesel consumption, which will avoid 100 kilotonnes of CO
2
 
emissions annually.
The
 
Roncador
field is in the offshore Campos basin and is operated by Petrobras. The field has been in production
 
since 1999. The
hydrocarbons are produced from two semi-submersibles and two FPSOs. The oil is offloaded to shuttle tankers, and the
 
gas is
drained out through pipelines to shore.
Canada
Equinor has interests in the
Jeanne d'Arc
basin offshore the province of Newfoundland and Labrador in the partner operated
producing oil fields
Hebron, Hibernia and Hibernia Southern Extension.
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
129
Africa
Algeria
In Salah
is an onshore gas field in the central Sahara area which consists of seven fields. The Northern
 
fields have been operating
since 2004. The Southern fields have been operating since 2016 and are tied back into the Northern
 
fields’
 
facilities.
In Amenas
is an onshore gas field which contains significant liquid volumes. The infrastructure
 
includes a gas processing plant which
is connected to the Sonatrach distribution system. In 2022, two gas turbine generators were reduced
 
to one, optimising power usage
and reducing emissions.
The In Amenas and In Salah licences are jointly operated by Sonatrach, Equinor and Eni. Separate
 
PSAs, including mechanisms for
revenue sharing, govern the rights and obligations of the parties.
Angola
The deep-water
blocks 17
,
15
and
31
contributed 34% of Equinor’s equity liquid production outside the NCS and the US in 2022.
Each block is governed by a PSA, which sets out the rights and obligations of the
 
participants, including mechanisms for sharing the
production with the Angolan state oil company Sonangol.
 
Block 17 has production from four FPSOs: CLOV, Dalia, Girassol and Pazflor. New projects on Dalia, CLOV,
 
and Pazflor are being
developed to stem a natural decline in production.
 
 
Block 15 has production from four FPSOs: Kizomba A, Kizomba B, Kizomba C-Mondo, and
 
Kizomba
 
C-Saxi Batuque. In 2022, there
was a new oil discovery in Bavuca South (Kizomba B area) which is planned to be
 
developed.
 
 
Block 31 has production from one FPSO producing from the PSVM fields.
 
 
The FPSOs serve as production hubs, which receive oil from more than one field through multiple
 
wells.
 
The operators in Angola are improving methane leak detection with aircraft-based surveys of offshore facilities. Implementation
 
of a
more stringent flaring policy reduced emissions in block 17. In addition, improvements to equipment reliability
 
and changes to
reservoir management reduced emissions in blocks 17 and 31.
 
Libya
Equinor has an ownership interest in two oil fields onshore in Libya,
Murzuq
and
Mabruk.
Mabruk was damaged during the conflict in
Libya in 2015. A project to re-develop the field is ongoing.
Nigeria
Agbami
is a deep-water field located off the coast of the Central Niger Delta region. The field straddles
 
the two licences OML 127 and
OML 128, operated by Chevron under a Unit agreement. The Agbami field is governed by a PSC.
For information related to the Agbami redetermination process, see note 26 Other commitments,
 
contingent liabilities and contingent
assets to the Consolidated financial statements.
Eurasia
Azerbaijan
Azeri-Chirag-Gunashli (ACG)
is an oil field located offshore Azerbaijan. The crude oil is sent to the Sangachal Terminal, where it is
processed prior to export. The Baku-Tbilisi-Ceyhan (BTC) pipeline is the main export route, in which
 
Equinor holds 8.71%. The
construction of the
Azeri Central East (ACE)
platform is in progress, and all engineering, procurement and onshore fabrication work
is expected to be completed in 2023.
Ireland
In November 2021 Equinor entered into an agreement with Vermilion Energy Inc to sell Equinor’s non-operated equity position in the
Corrib
 
gas field offshore Ireland. The effective date for the transaction was 1 January 2022. Closing is expected in the
 
first quarter of
2023.
For more information about the transaction see note 6 Acquisitions and disposals to the Consolidated
 
financial statements.
United Kingdom
Mariner
is a heavy oil field located in the North Sea, east of the Shetland Islands, which
 
is operated by Equinor. The field has one
combined platform for production, drilling and accommodation. Oil is exported by offshore loading from a floating
 
storage unit.
Production from the field started in August 2019.
The
 
Statfjord Unit
field is one of the Equinor-operated fields in the Statfjord area, which spans the boundary
 
between the NCS and
UKCS. The Statfjord Unit development covers the Statfjord A, B and C platforms.
 
International exploration
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
130
 
Equinor, Annual Report on Form 20-F 2022
 
In 2022, Equinor and its partners drilled and completed two wells in
Angola
, one well in
Brazil
, and three wells in
Canada
. In
Argentina
onshore, Equinor and partners completed drilling of six appraisal wells in the Bajo
 
del Toro licence in Vaca
 
Muerta and
started test production in July. In
Algeria,
 
Equinor decided to exit the Timmisit licence.
Exploratory wells
drilled
1)
 
For the year ended 31 December
2022
2021
2020
Americas (excluding US)
Equinor operated
3
0
3
Partner operated
7
2
3
Africa
Equinor operated
0
0
0
Partner operated
2
0
1
Other regions
Equinor operated
0
1
0
Partner operated
0
0
4
Total (gross)
12
3
11
1) Wells completed during the year, including appraisals of
earlier discoveries.
Fields under development internationally
Americas (excluding US)
Brazil
Bacalhau
(Equinor 40%, operator) oil and gas discovery straddles
BM-S-8
and
Bacalhau North
in the Santos basin, off the coast of
the state of Sao Paulo.
The investment decision for Bacalhau phase 1 was made in June 2021. The field is being
 
developed with subsea wells tied back to an
FPSO, and first oil is scheduled for 2025. In November 2022, the first production well was
 
spudded.
A second phase of the Bacalhau field development is being considered to fully exploit the value
 
potential.
Discoveries with potential for development
Americas (excluding US)
Brazil
BM-C-33
(Equinor 35%, operator) includes the oil and gas discoveries
Pao de Acucar
,
Gavea
and
Seat
in the southwestern part of
the Campos basin, off the coast of the state of Rio de Janeiro, Brazil. The project is maturing towards sanction. A gas
 
export solution
is under consideration.
Canada
Bay du Nord
(Equinor 65% now, 58.5% anticipated at sanction, operator) is an oil field in the Flemish pass basin which was
discovered by Equinor in 2013. The field is around 500 km northeast of St. John’s in Newfoundland
 
and Labrador, Canada.
Developing Bay du Nord and nearby discoveries in a subsea solution tied back to an FPSO
 
is under consideration. In April 2022, the
federal Canadian authorities approved the environmental impact assessment. The renegotiation of a framework
 
agreement with the
government of Newfoundland and Labrador has started.
Africa
Tanzania
Block 2
(Equinor 65%, operator). Equinor made several large gas discoveries in block 2 in
 
the Indian Ocean, off southern Tanzania,
between 2012 and 2015. The partners of block 2 (Equinor, operator) and blocks 1 and 4 (Shell, operator) are collaborating on the
future development of the discoveries and are jointly negotiating with the government of Tanzania. On 11 June, 2022, the partners
signed a Framework Agreement with the government of Tanzania, aligning on some of the key fundamentals needed for the
development of an LNG project.
Equinor, Annual Report on Form 20-F 2022
 
131
Eurasia
Azerbaijan
The
Karabagh
(Equinor 50%, operated by Karabagh Joint Operating Company
)
field is located off the coast of Azerbaijan. In 2018
Equinor entered into an agreement with SOCAR (the Azerbaijani state oil company) to
 
enter the Karabagh and Ashrafi-Dan Ulduzu-
Aypara (ADUA) exploration licences with a 50% share in each.
A joint operating company was formed in 2020 and started working on the field development
 
solution.
United Kingdom
The
Rosebank
(Equinor 40%, operator) oil and gas field is located northwest of the Shetland Islands,
 
on the UKCS. Equinor and its
licence partners continue to mature and improve the business case for its development. Equinor’s
 
stake in Rosebank will increase to
80% with the acquisition of Suncor Energy UK Limited, announced on 3 March 2023. The transaction
 
is subject to regulatory approval
and is expected to be completed in mid-2023.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
exhibit154p132i0
132
 
Equinor, Annual Report on Form 20-F 2022
 
3.1.3 Exploration & Production USA
The Exploration & Production USA (E&P USA) reporting segment covers exploration,
 
development and production of oil and gas in
the US.
E&P USA produced around 16% of Equinor’s total equity production of oil and gas
 
in 2022, compared to 18% in 2021.
Equinor has continued shaping the US oil and gas portfolio, focusing activity in areas with high
 
value potential, and
continues to optimise its strong asset base.
In 2022, Equinor entered into a Cooperation Agreement with Shell and US Steel to advance
 
a collaborative clean energy hub in the
tri-state region of Ohio, West Virginia and Pennsylvania. The hub will focus on decarbonisation opportunities such
 
as carbon capture
utilisation and storage (CCUS), as well as blue hydrogen production and utilisation. In 2022, Equinor
 
also signed a memorandum of
understanding (MOU) with Battelle, the world’s largest independent research and development company, to work together on
assessing the tri-state area’s carbon storage potential.
Key events
 
●
 
On 5 May, Equinor received a 60% interest and operatorship
 
in
North Platte
. This followed TotalEnergies decision, in February 2022, to not sanction the project
 
and to withdraw from it.
●
 
On 29 June, Equinor transferred 51% of its interest in the
North
 
Platte
 
deep water development project in the US Gulf of Mexico.
 
Equinor retained a 49% interest in the project, and Shell will
 
become the new operator of the field.
 
The development was
 
renamed to
Sparta
 
to reflect this change.
●
 
On 16 February 2023, production started on the
Vito
 
platform in the
 
US Gulf of Mexico, capable of producing 100,000 barrels of oil
per day.
 
Equinor has a 36.89% interest in the field, which is
 
operated by Shell Offshore Inc.
Performance review
E&P USA - condensed income statement under
 
IFRS
For the year ended 31 December
(in USD million)
2022
2021
22-21 change
Revenues
5,523
4,149
33%
Total revenues and other income
5,523
4,149
33%
Operating, selling, general and administrative expenses
(938)
(1,074)
13%
Depreciation, amortisation and net impairment losses
(361)
(1,734)
79%
Exploration expenses
(201)
(190)
(6%)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
133
Net operating income/(loss)
4,022
1,150
>100%
For the year ended 31 December
Operational information
2022
2021
22-21 change
E&P equity liquids and gas production (mboe/day)
324
373
(13%)
E&P entitlement liquid and gas production (mboe/day)
279
321
(13%)
Royalties
44
52
(14%)
Average liquids price (USD/bbl)
81.0
58.3
39%
Average internal gas price (USD/mmbtu)
5.55
2.89
92%
Operational performance
The average daily production of liquids and gas declined by 13%, mainly due to Equinor’s
 
divestment of its Bakken assets in 2021 in
addition to the natural decline from our operated and non-operated onshore assets in the Appalachian
 
Basin. Furthermore, Caesar
Tonga
 
was impacted by more unexpected down-time and planned turnarounds in 2022,
 
driving Gulf of Mexico production down 3%.
Financial performance
 
Higher realised liquids and gas prices were the main drivers for the increase in revenues in
 
2022 compared to 2021.
 
This was
partially offset by lower entitlement production.
Operating expenses decreased due to lower transportation related costs resulting from lower production
 
and the divestment of
Bakken partially offset by higher operations and maintenance expenses.
Depreciation decreased due to lower production and improved reserves partially offset by effects from impairment reversals and
additional investments during 2022.
Net impairment reversals related to property, plant, and equipment amounted to USD 1,060 million in 2022 driven primarily by
improved short-term commodity price assumptions compared to net impairments of USD 69 million in 2021.
Expensing of a non-commercial exploration discovery in the Gulf of Mexico was the main
 
driver
for the increase in exploration
expenses in 2022 compared to 2021.
Balance sheet information:
 
The sum of equity accounted investments and non-current segment assets was USD
 
11,311
 
million for
the year ending 31 December 2022, compared to USD 11,406 million for the year ending 31 December 2021.
US production
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
exhibit154p134i0
134
 
Equinor, Annual Report on Form 20-F 2022
 
Entitlement production differs from equity production in the USA where entitlement production is expressed net of royalty
 
interests.
Equity production represents volumes that correspond to Equinor’s percentage
 
ownership in a particular field and is larger than
Equinor’s entitlement production where the royalties are excluded from entitlement
 
production.
For further detailed production data see section 5.5 Production per field.
Equinor's entitlement production in the USA was 15% of Equinor's total entitlement production in 2022.
Average daily entitlement production
For the year ended 31 December
2022
2021
2020
Oil and NGL
 
Natural gas
Oil and NGL
 
Natural gas
Oil and NGL
 
Natural gas
Production area
mboe/day
mmcm/day
mboe/day
mboe/day
mmcm/day
mboe/day
mboe/day
mmcm/day
mboe/day
USA
 
114
 
 
26
 
 
279
 
 
128
 
 
31
 
 
321
 
 
163
 
 
29
 
 
344
 
Offshore Gulf of Mexico
The
Titan
 
oil field is an Equinor-operated asset located in the Mississippi Canyon and is
 
producing through a floating spar facility.
The
Tahiti, Heidelberg, Caesar Tonga and Stampede
 
oil fields are partner operated assets located in the Green Canyon area. The
Tahiti and Heidelberg oil fields produce through floating spar facilities. The Caesar Tonga oil field is tied back to the Anadarko-
operated Constitution spar host. The Stampede oil field produces
 
through a tension-leg platform with downhole gas lift.
The
Jack, St. Malo, Julia
 
and
Big Foot
 
oil fields are partner-operated assets located in the Walker Ridge area. The Jack, St. Malo
and Julia oil fields are subsea tiebacks to the Chevron-operated Walker Ridge regional host facility. The Big Foot oil field produces
through a dry tree tension-leg platform with a drilling rig.
Onshore portfolio
Since its entry into US shale in 2008, Equinor has continued to optimise its portfolio
 
through acreage acquisitions and divestments.
Equinor has an ownership interest in the
Marcellus
 
shale gas play, located in the
Appalachian
 
region in northeast US. The position
is mostly partner operated. Since 2012, Equinor has also been an operator in the Appalachian
 
region in the state of Ohio, developing
the Marcellus and Utica formations.
In addition, Equinor participates in natural gas gathering system and gas treatment and processing
 
facilities in Appalachian basin
assets to provide flow assurance for Equinor's upstream production.
For further detailed production data and information see section 5.5 Production per field.
Equinor, Annual Report on Form 20-F 2022
 
135
US exploration
Throughout 2022, Equinor continued its activity in US Gulf of Mexico, which is one
 
of our core areas for exploration.
Equinor completed drilling an operated appraisal well located in the Walker Ridge area of the
US Gulf of Mexico
 
in 2022 which was
deemed non-commercial. In addition, Equinor was awarded one lease in 2022.
Fields under development in the US
Offshore Gulf of Mexico
The
Vito development project
 
(Equinor 36.89%, operated by Shell) is a Miocene oil discovery located in the Mississippi
 
Canyon
area. The development project consists of a light-weight semisubmersible platform with a single eight-well subsea manifold.
 
The
project was sanctioned for development in April 2018.
 
On 16 February 2023, production started on the Vito platform, capable of
producing 100,000 barrels of oil per day.
 
The
St. Malo water injection project
 
(Equinor 21.50%, operated by Chevron) is a secondary depletion project sanctioned in 2019.
Both production wells are online, and two injector wells have been drilled. Both injector
 
completions and the last injector conversion
were completed in the second half of 2022.
Discoveries with potential for development
Offshore Gulf of Mexico
Sparta
(formerly North Platte) (Equinor 49%, operated by Shell) is a Paleogene oil discovery
 
in the Garden Banks area. It has been
fully appraised since its discovery with three drilled wells and three sidetracks. In February 2022, the
 
operator notified Equinor and the
relevant authorities of its decision to withdraw from the North Platte project. In May
 
2022, Equinor received a 60% interest and the
operatorship from TotalEnergies.
 
Subsequently,
 
in June 2022, Equinor assigned 51% interest and operatorship to Shell. The project
was also renamed Sparta.
136
 
Equinor, Annual Report on Form 20-F 2022
 
3.2 High-value growth in renewables
Developing a high-value renewables business
Equinor continues to make progress on its strategic aim to accelerate profitable growth in renewables.
 
We aim to install 12-16 GW of renewables capacity and produce 35-60 TWh annually by 2030. We will achieve this by becoming
 
a
global offshore wind major and establishing ourselves as a market driven power producer in selected markets by
 
pursuing
opportunities in onshore renewables and taking on more merchant risk exposure.
 
In 2022, we achieved first power from Hywind Tampen (our first commercial-scale floating wind farm, which delivers renewable power
to the Gullfaks and Snorre oil and gas platforms in the North Sea)
 
and Stępień (our first Polish solar farm which entered the portfolio
as part of the Wento acquisition in 2021). During the year we continued to strengthen our floating
 
wind leadership by winning a ~2GW
lease in Morro Bay, California. We also acquired two medium-sized onshore platforms: East Point Energy (a battery storage
developer) and BeGreen (a Danish onshore developer).
 
We remain value-driven and use different value drivers from project development and execution, to trading and power market risk
management. We also use select divestments to drive and shape business models for different markets. The renewable
 
industry is
developing fast, costs are increasing, power prices are high, and the supply chain is tightening.
 
We remain disciplined in expensive
offshore wind auctions and have accelerated our pace to become more market driven.
 
Equinor is evolving into an integrated power producer with a diversified power portfolio. As
 
power markets mature, our strategic pillars
are merging to become multi-market and multi-technology. We see opportunities will come in the form of broad energy offerings,
managing merchant risk, growing our offshore wind position, and cementing our floating wind leadership.
Overview
Offshore wind
We are developing as a global offshore wind major, powering European homes with renewable electricity from offshore wind farms in
the UK and Germany and building material clusters in the North Sea, the Baltic Sea and
 
the US. In parallel, we are actively positioning
ourselves to access emerging markets globally. Equinor sees potential for floating offshore wind projects in Norway, Europe, the US
and Asia and is accelerating the development of this technology to strengthen our position in the industry. Floating wind is still at an
early development phase compared to other renewable energy sources.
Equinor has long experience with offshore wind power in the
UK
, having built and brought into operation Sheringham Shoal (Equinor
40%, operator), Dudgeon (Equinor 35%, operator) and Hywind Scotland (Equinor 75%, operator). Together with the partners we are
also developing Dudgeon extension project and Sheringham Shoal extension project. Together with our partners SSE Renewables
and Vårgrønn we are developing Dogger Bank, the world’s biggest offshore wind farm (Equinor 40%, operated
 
by SSE Renewables
during the development phase. Equinor assumes operatorship when the windfarms come on stream). Some
 
of the capital expenditure
is financed through project financing. At year-end 2022, Equinor’s share of the
 
project financing debt for the Dudgeon project
amounted to USD 0.4 billion, and for the Dogger Bank projects USD 1.9 billion.
Equinor is pursuing the development of offshore wind projects on the east and west coast of the
US
. Together with our partner bp
Equinor is pursuing the development of the Empire Wind and Beacon Wind
 
offshore wind projects (Equinor 50%, operator). The
Empire Wind 1 & 2 and Beacon Wind 1 projects have been selected to provide
 
New York State with offshore wind power and will
provide a total of 3.3 gigawatts (GW).
As the provisional winner of a lease area on the California Pacific outer continental shelf, Equinor
 
continues to lead the way in growing
the offshore wind industry in the US. With a bid of USD 130 million for 80,062 acres in the Pacific
 
Ocean, Equinor secured a lease of
around 2 GW in the Morro Bay area which has the potential to generate enough energy to power
 
some 750,000 US homes.
In
Poland
, Equinor has an interest (50%, operator) in the three Baltyk offshore wind development projects (MFW
 
Baltyk III, MFW
Baltyk II and MFW Baltyk I). Through this position, we can build scale and value in what we see
 
as an important energy region.
Norway
 
and the
North Sea
 
have some of the world’s best wind resources. Large-scale offshore wind can create new industrial
opportunities for Norway. We have developed the first floating offshore wind farm to supply renewable power to oil and gas
installations in Norway.
 
The Snorre and Gullfaks oil and gas platforms are the first ever with power supply
 
from a floating offshore
wind farm.
exhibit154p137i0
 
 
Equinor, Annual Report on Form 20-F 2022
 
137
In addition to our offshore wind presence in the UK, the US, Poland and Norway, we are present in
Germany, Japan, South Korea,
France, Spain
 
and
Vietnam
.
We are a partner (25%) in the
Arkona
 
offshore windfarm in Germany, located in the Baltic Sea. The wind farm started production in
2019.
Together with our partners, the Korea National Oil Corporation and Korea East-West Power CO, we have the ambition to develop a
floating offshore wind farm in
South Korea
 
(Donghae 1). We have also started conducting the wind measurements that are needed to
assess the potential for developing a floating offshore wind project (Firefly).
Onshore renewables
Solar portfolio
With the increasing demand for solar, wind and storage solutions as integrated parts of the energy system, Equinor is gradually
growing its presence in onshore renewables in selected power markets.
 
In
Brazil
, Equinor has an interest in Apodi (Equinor 43.75 %, operated by Scatec), and the
 
plant started production in 2018. The final
investment decision was made in the fourth quarter of 2022 on the 531 MW Mendubim
 
solar project in Brazil (Equinor 33.3%,
operated by Scatec), and the financial close of the project was also reached in the fourth
 
quarter of 2022.
Equinor has an interest in the 117 MW Guañizuil II A solar producing plant in Argentina (Equinor 50%, operated by Scatec).
In 2021, Equinor acquired the Polish solar developer
Wento
(Equinor 100%). Its first solar plant, Stępień, was ready for operations in
October 2022, and two more reached final investment decision with production expected to start in
 
2023/2024.
In November, Equinor signed an agreement to acquire 100% of the shares in
BeGreen,
 
based in Denmark, a leading solar project
developer in Northwest Europe. The transaction closed on 26 January 2023 after receiving the
 
necessary regulatory approvals.
Equinor holds a 13.1% ownership share in Scatec, an integrated independent renewable power producer. This financial investment is
included in the Other Group reporting segment.
Storage systems and other activities
Equinor sees a solid opportunity to create profitable businesses by deploying batteries and energy
 
storage assets to satisfy the
growing need to stabilise power markets, either as a part of offshore or onshore renewable assets or as separate
 
units supplying
services to the grid. In 2022, Equinor signed an agreement to buy a 100% stake in the
 
US-based battery storage developer East Point
Energy LLC. The acquisition provides a platform for broadening our energy offerings in the US.
In 2022, Equinor reached final investment decision on the Blandford Road battery storage project
 
in UK. This is the first commercial
battery storage asset for Equinor, and the first project realised from the strategic partnership between Equinor and Noriker Power. The
project will start construction in January 2023 and is expected to be operational by late 2023.
Equinor is also exploring opportunities and cooperation within the green hydrogen
 
sector. Hydrogen is expected to become an
integrated part of future energy systems and Equinor is taking positions adding clean hydrogen
 
as an enabler for the transport and
storage of clean energy produced by renewables.
The renewable portfolio has been strengthened in 2022 and early 2023 through the following
 
milestones:
Offshore wind
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
138
 
Equinor, Annual Report on Form 20-F 2022
 
●
 
On 22 February, Equinor and partner Polenergia selected
Siemens Gamesa
 
as the preferred supplier of wind turbine
generators for the
MFW Bałtyk II
 
and
MFW Bałtyk III
 
projects, two of the largest and most advanced offshore wind farms
being developed in Poland, with a total installed capacity of 1,440 MW.
●
 
On 3 March, Equinor and bp signed an agreement to transform
South Brooklyn Marine Terminal (SBMT)
 
in Brooklyn, New
York into a world-class offshore wind staging and assembling facility and to become the
operations and maintenance
(O&M) base
 
both for the
Empire Wind
 
and
Beacon Wind
 
projects, as well as for the growing US offshore industry on the
East Coast.
●
 
On 6 April, Equinor teamed up with Naturgy to enter a development agreement prior to Spain’s first upcoming
 
offshore wind
auction off the coast of the Canary Islands in 2023.
 
●
 
On 29 April, the
Dogger Bank Wind Farm
 
announced the start of offshore construction work with the installation of export
cable off the Yorkshire coast.
●
 
On 13 November, Equinor started production at
Hywind Tampen
, Norway’s first and the world’s largest floating wind farm.
The power will be delivered to the Gullfaks and Snorre platform in the North Sea.
●
 
On 7 December, Equinor became the provisional winner of a lease area in California,
 
which will strengthen its floating
offshore wind position.
Onshore renewables
●
 
On 12 July, Equinor signed an agreement to buy a 100% stake in the US based battery storage developer
East Point
Energy LLC
.
 
●
 
On 3 October, Equinor approved
 
the final investment decision on the
Blandford Road battery storage
 
project in the south
of the UK. This is the first commercial battery storage asset for Equinor, and the first project realised from the strategic
partnership between Equinor and Noriker Power. Construction will start in January 2023 and the project is expected to be
operational in the third quarter of 2023.
●
 
On 4 October, Equinor’s first solar plant in Poland (
Stępień
 
with 58MW capacity) was completed and ready for operation.
Stępień was developed and will be operated by Wento, Equinor’s wholly-owned subsidiary.
●
 
On 2 November, Equinor signed an agreement to acquire
BeGreen
, a leading solar project developer in Northwest Europe,
as a wholly-owned Equinor subsidiary.
●
 
On 7 December, Equinor made final investment decision on the 531 MW
Mendubim
solar project in Brazil. Early phase
construction works of this project started in summer 2022 and realized in partnership with
 
Scatec and Hydro Rein. Equinor
has 33.3% in the project.
Performance review
REN - condensed income statement under IFRS
For the year ended 31 December
(in USD million)
2022
2021
Change
Revenues
16
8
94%
Net income/(loss) from equity accounted investments
58
16
>100%
Other income
111
1,386
(92%)
Total revenues and other income
185
1,411
(87%)
Operating, selling, general and administrative expenses
(265)
(163)
(63%)
Depreciation, amortisation and net impairment losses
(4)
(3)
(11%)
Net operating income/(loss)
(84)
1,245
N/A
For the year ended 31 December
(in USD million)
2022
2021
Change
Renewables power generation (GWh) Equinor
 
share
1,641
1,562
5%
Equinor, Annual Report on Form 20-F 2022
 
139
Operational performance
Power generation (Equinor share)
 
was 1,641 GWh (gigawatt hours) in the full year of 2022, compared to 1,562 GWh
 
in the full year of
2021. The increase was mainly due to the start-up of production from the Guanizuil IIA
 
solar plant in the third quarter of 2021. 
In 2022, our equity-based installed renewable energy capacity was 0.6 GW. By 2026 Equinor expects to significantly increase
installed capacity from renewable projects under development, mainly based on the current project portfolio. Towards 2030, Equinor
expects to increase installed renewables capacity further to between 12 and 16 GW and to produce
 
35-60 TWh annually. We are
progressing to deliver on the ambitions.
For 2022, additions to PP&E, intangibles and equity accounted investments amounted to USD 298
 
million, while gross capex* from
the renewable business amounted to USD 1.3 billion. Equinor’s ambition is to have more
 
than 50% of our gross capex* allocated to
renewable and low carbon solutions in 2030, and we are on track to deliver on our ambitions.
 
In our renewables business, we demonstrated real progress in 2022 on both project execution and on
 
building the portfolio pipeline. In
addition to laying the first foundations at the Dogger Bank offshore wind farm in the UK and completion
 
of the Stępień solar project in
Poland, we put in place further building blocks for our renewables strategy.
Financial performance
 
Net operating income was negative USD 84 million in 2022 compared to positive USD
 
1,245 million in 2021. The decrease was mainly
due to significant gains on divestments in 2021 of around USD 1.4 billion.
In 2022, Other income was impacted by a gain of USD 87 million related to the divestment of a 10%
 
stake in the Dogger Bank C wind
farm project in the UK. In 2021, Other income was impacted by gains of USD 1,386 million related
 
to the sale of a 50% stake in the
Empire Wind and Beacon Wind assets in the U.S.
Net income from equity accounted investments was positively impacted by income from producing
 
assets in both periods, partially
offset by losses from projects under development due to the expense of project development costs. The increased
 
net income from
equity accounted investments in 2022 was mainly due to a lower portion of project costs being
 
expensed because the Empire Wind
project in the US started capitalisation of project costs in the first quarter of 2022. 
Operating expenses and selling, general and administration expenses increased due to higher business
 
development costs, driven by
higher activity levels in the USA, the UK and Asia.
Balance sheet information:
 
The sum of equity accounted investments and non-current segment assets was USD
 
1,768 million for
the year ending 31 December 2022, compared to USD 1,265 million for the year ending 31 December
 
2021.
exhibit154p140i0
140
 
Equinor, Annual Report on Form 20-F 2022
 
3.3 Marketing, midstream and processing (MMP), including
 
new
market opportunities in low carbon solutions
Secure premium market access, grow value creation through cycles and build a low carbon
business
 
MMP works to maximise value from Equinor’s equity production of oil and
 
gas for the producing units and to capture value from
Equinor’s global mid-
 
and downstream positions through marketing, trading and optimisation. The operating segment
 
also has
responsibility for marketing of the Norwegian state’s natural gas and crude on from the Norwegian continental
 
shelf and for the
development of value chains to ensure flow assurance for Equinor’s upstream
 
production and to maximise value creation.
As part of the Equinor group, Danske Commodities (DC), one of Europe’s largest electricity traders, supports Equinor’s
 
strategy to
build a profitable power and renewables business. A key strategic driver for the acquisition of
 
DC was to capture value from
increasingly volatile gas and power markets, contributing to take down volatility by moving
 
energy from where there is plenty to where
demand is highest by responding to price signals and utilising capacity. In addition, MMP is responsible for developing low carbon
value chains for Equinor, with key focus on transforming natural gas to clean hydrogen and developing carbon capture, usage and
storage (CCUS) projects.
MMP’s global trading business with its Asset-Backed Trading strategy is positioned to deliver value from absolute prices as well
 
as
from expected continued volatile energy markets.
Overview
MMP is responsible for marketing, trading, processing and transporting crude oil and condensate,
 
natural gas, natural gas liquids
(NGL) and refined products, including the operation of a refinery, terminals and processing plants.
MMP is also responsible for power and emissions trading and for developing transportation solutions for
 
natural gas, liquids and crude
oil from Equinor assets, including pipelines, shipping, trucking and rail. In addition, MMP is responsible
 
for Equinor’s low carbon
solutions. The business activities within MMP are organised in the following business clusters:
 
Crude, Products and Liquids (CPL),
Gas and Power (G&P), Operating Plants (OPL), Low Carbon Solutions (LCS), Data improvements, Shipping
 
and Commercial
operations (DISC) and New Value Chains (NVC).
Equinor, Annual Report on Form 20-F 2022
 
141
MMP markets, trades and transports approximately 60% of all Norwegian liquids export, including
 
Equinor equity, the Norwegian
State’s direct financial interest (SDFI) equity production of crude oil and NGL, and third-party volumes. MMP is
 
also responsible for the
marketing, trading and transportation of Equinor and SDFI dry gas and LNG together with third-party
 
gas. This represents
approximately 70% of all Norwegian gas exports.
 
For more information, see note 7 Total revenues and other income to the Consolidated financial statements for Transactions with the
Norwegian State, and chapter 5.1 Board statement on corporate governance – subsection 4. Equal treatment of shareholders
 
and
transactions with close associates, for the Norwegian State’s participation and SDFI oil and gas marketing
 
and sale.
exhibit154p142i0
142
 
Equinor, Annual Report on Form 20-F 2022
 
Key events
Russia’s invasion of Ukraine had a significant impact on European energy markets in 2022, resulting
 
in high prices and volatility for
gas, power and oil.
 
As a result of the energy crunch in Europe, MMP and E&P Norway worked
 
with partners and government
authorities to increase gas exports to Europe through increased production permits, reduced gas
 
injection, and the optimisation of
NGL to increase gas calorific value. Equinor decided to withdraw from Russia and stop
 
trading in Russian oil and oil products from
March 2022.
Equinor, Annual Report on Form 20-F 2022
 
143
●
 
On April 5, Equinor was awarded the operatorship for the development of the Smeaheia CO
2
 
storage in the North Sea. Smeaheia
is important for developing the NCS into a leading region for CO
2
 
storage in Europe.
 
●
 
In May 2022 the North Sea Transition Authority (NSTA) awarded Equinor and bp, as joint licensees, two carbon storage (CS)
licences in the Southern North Sea (UK).
●
 
The LPG terminal in Port Klang in Malaysia received its first commercial LPG shipment late
 
May 2022. Equinor is the sole user of
the terminal via a 7-year lease agreement. This represents an important milestone in Equinor’s
 
LPG strategy.
 
●
 
After extensive repair and improvement work, Hammerfest LNG was brought back in production with the
 
first refrigerated
liquefied natural gas (LNG) delivered to tank at Melkøya on 2 June 2022.
 
●
 
On June 9, Equinor and Cheniere announced a 15-year purchase agreement of around 1.75
 
million tonnes of LNG per year
starting from 2026. The new sales and purchase agreement (SPA) adds new volumes to Equinor’s already significant gas
portfolio of pipeline gas and LNG.
●
 
Equinor joined the Mærsk Mc-Kinney Møller Centre for Zero Carbon Shipping in June
 
2022, committing to a long-term strategic
collaboration on the development of zero carbon technologies for the deep-sea maritime industry.
●
 
In June, Equinor and SSE Thermal announced acquisition of power the company Triton Power from Energy Capital Partners
(ECP). The two companies will start preparations to use hydrogen in the Saltend Power
 
Station. The acquisition was completed
on 1 September 2022.
 
●
 
In July, Fluxys and Equinor launched a large-scale decarbonisation solution for North West Europe. The two companies agreed
to develop a major infrastructure project for transporting captured CO
2
 
from emitters to safe storage sites in the North Sea,
connecting Belgium and Norway. The project is in the feasibility stage, with an investment decision expected by 2025.
●
 
On August 12, the UK Department for Business, Energy, and Industrial Strategy (BEIS) announced that Equinor’s H2H Saltend
production facility, as well as new gas-fired power stations with carbon capture at Keadby (developed with SSE Thermal) and in
Teesside (with bp) had been successfully shortlisted through Phase-2 of the UK government’s cluster sequencing process.
●
 
In August, Northern Lights, a joint venture owned by Equinor, Shell and TotalEnergies, signed the world’s first commercial
agreement on cross border CO
2
 
transportation and storage with Yara.
 
●
 
On August 30, Equinor and Wintershall Dea agreed to pursue the development of a CCS
 
value chain connecting continental
European CO
2
 
emitters to offshore storage sites on the NCS (Smeaheia). A 900-kilometre open access pipeline is planned to
connect a CO
2
 
collection hub in Northern Germany and Norway prior to 2032.
●
 
In September Equinor announced a long-term gas sales agreement with the leader of the Polish
 
natural gas market, PGNiG. The
agreement is for 10 years with a volume of around 2.4 billion cubic metres (bcm) of gas per year to
 
be exported through the new
Baltic Pipe.
●
 
In October, following developments in the European and Norwegian security situation, with unidentified drone observations and
suspected pipeline sabotage in the Baltic Sea, our strategic project team for the European security
 
situation was continued to
strengthen security measures for Onshore plants and pipelines.
●
 
In January 2023 Equinor has awarded a Front-End Engineering Design (FEED) contract for H2H
 
Saltend, a 600-megawatt low
carbon hydrogen project with carbon capture in the UK, to Linde Engineering, and an
 
operation and maintenance service contract
to BOC. Linde Engineering together with BOC participated in a design competition to provide proposals
 
for FEED with options for
Engineering, Procurement and Construction (EPC) and Operation and Maintenance for the first five
 
years.
●
 
In January 2023 Equinor and RWE signed a memorandum of understanding (MoU) to jointly develop large-scale energy
 
value
chains, building on the partnership between Norway and Germany and the long-term relationship between Equinor
 
and RWE.
The partners aim to replace coal fired power plants with hydrogen-ready gas fired power
 
plants in Germany, and to build
production of low carbon and renewable hydrogen in Norway that will be exported
 
through pipeline to Germany.
MMP presence across the world
 
exhibit154p144i0
144
 
Equinor, Annual Report on Form 20-F 2022
 
Marketing and trading of gas, LNG and power
MMP is responsible for the sale of Equinor’s and SDFI’s dry gas and LNG. Equinor’s gas
 
marketing and trading business is conducted
from Norway and from offices in Belgium, the UK, Germany and the US. Through the acquisition of Danske Commodities
 
(DC), a
trading company for power and gas, MMP also strengthened Equinor´s energy trading
 
business, as well as its investments in in
renewables. DC is primarily active in Europe but also operates in the US.
 
Europe
 
The major export markets for natural gas produced from the NCS are the UK, Germany, France, the Netherlands and Belgium. LNG
from the Snøhvit field
8
, combined with third-party LNG cargoes, allows Equinor to reach global gas markets. The gas
 
is sold to
counterparties through bilateral sales agreements and over the trading desk. Some of Equinor’s
 
long-term gas contracts have price
review clauses which can be triggered by the parties. 
 
For ongoing price reviews, Equinor provides in its financial statements for probable liabilities based
 
on Equinor’s best judgement. For
further information, see note 26 Other commitments, contingent liabilities and contingent assets to the Consolidated
 
financial
statements.
 
 
Equinor is active on both the physical and exchange markets, such as the Intercontinental Exchange
 
(ICE) and Trayport. Equinor
expects to continue to optimise the value of the gas volumes through a mix of
 
bilateral contracts and over the trading desk, via its
production and transportation systems and downstream assets. MMP receives a marketing
 
fee from E&P Norway for the Norwegian
gas sold on behalf of the company.
 
DC is active on both the physical and exchange markets for both gas and power as a separate
 
entity. All trading and optimisation of
power in Equinor is performed by DC.
 
From 1 September 2022 Equinor held 50% of Triton Power in a joint venture with SSE Thermal.
USA
 
Equinor Natural Gas LLC (ENG), a wholly owned subsidiary, has a gas marketing and trading organisation in Stamford, Connecticut
that markets natural gas to local distribution companies, industrial customers, power generators
 
and other gas trading counterparties.
ENG also markets equity production volumes from the Gulf of Mexico and the Appalachian Basin
 
and transports some of the
8
 
Gas production from the Snøhvit field was suspended after the fire at the Hammerfest LNG plant
 
September 2020. Production
resumed in
 
early June 2022.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
145
Appalachian production to New York City and into Canada to the greater Toronto area. In addition, ENG has capacity contracts at the
Cove Point LNG re-gasification terminal.
Marketing and trading of liquids
MMP is responsible for the sale of Equinor’s and SDFI’s crude oil and NGL produced on the NCS, in
 
addition to the operation and
commercial optimisation of Equinor’s refineries and terminals. MMP also markets
 
the equity volumes from the company´s assets
located in the US, Brazil, Canada, Angola, Nigeria, Algeria, Azerbaijan and the UK, as well
 
as third-party volumes. The value is
maximised through marketing, physical and financial trading and through the optimisation of owned
 
and leased capacity such as
refineries, processing, terminals, storages, pipelines, railcars and vessels.
 
The liquids marketing and trading business is conducted from Norway, the UK, Singapore, the US and Canada. The main crude oil
market for Equinor is Northwest Europe.
 
Manufacturing
Equinor owns and operates the Mongstad refinery in Norway, including a combined heat and power plant (CHP). The refinery is a
medium-sized refinery built in 1975, with a crude oil and condensate distillation capacity of 226,000
 
barrels per day. The refinery is
supplied via the Mongstad Terminal DA linked to offshore fields through three crude oil pipelines, a pipeline for NGL’s connecting
to Kollsnes and Sture (the Vestprosess pipeline) and to Kollsnes by a gas pipeline. The CHP plant was replaced with a new heater
solution in the third quarter of 2022, resulting in an estimated net emissions reduction of 250,000
 
tonnes of CO
2
 
per year.
Equinor holds an ownership interest in the methanol plant at Tjeldbergodden (82 %). The plant
 
receives natural gas from fields in the
Norwegian Sea through the Haltenpipe pipeline. In addition, Equinor holds an ownership interest
 
in the air separation
unit Tjeldbergodden Luftgassfabrikk DA (50.9%).
The following table shows distillation/production capacity and throughput for the Mongstad refinery
 
and for Tjeldbergodden methanol
plant.
 
Refinery margins continued to increase in 2022 due to tight markets for products
 
and restriction imposed on the purchase of
Russian products. The lower throughput for Mongstad & Tjeldbergodden in 2022 is mainly
 
due to higher planned and unplanned
shutdowns.
Throughput
1)
Distillation/Production
capacity
2)
Refinery
2022
2021
2020
2022
2021
2020
Mongstad
9.9
11.1
9.7
9.3
9.3
9.3
Tjeldbergodden
0.6
0.6
0.9
1.0
1.0
1.0
1)
Actual throughput of crude oils, condensates and other
 
feed, measured in million tonnes.
Throughput may be higher than the distillation
 
capacity for the plants because the volumes
of fuel oil etc. may not go through the crude-/condensate
 
distillation unit.
2)
Nominal crude oil and condensate distillation capacity, and methanol production
 
capacity,
measured in million tonnes.
Equinor is technical service provider (TSP) for the Kårstø and Kollsnes gas processing plants in accordance with
 
the technical service
agreement between Equinor and Gassco AS. Equinor holds an ownership interest in Vestprosess (34%), which transports and
processes NGL and condensate. Vestprosess is also operated by Gassco, with Equinor as TSP.
 
Equinor holds 30.1% interest in the Nyhamna gas processing plant operated by Gassco.
Terminals,
 
storage and pipelines
Equinor operates the Mongstad crude oil terminal (Equinor: 65%). The crude oil is landed at Mongstad
 
through pipelines from the
NCS and by crude tankers from the market. The Mongstad terminal has a storage capacity
 
of 9.4 million barrels of crude oil.
Equinor operates the Sture crude oil terminal. The crude oil is landed at Sture through
 
pipelines from the North Sea. The terminal is
part of the Oseberg Transportation System (Equinor: 36.2%). The processing facilities at Sture stabilise the crude oil and recover an
LPG mix (propane and butane) and naphtha.
146
 
Equinor, Annual Report on Form 20-F 2022
 
Equinor operates the South Riding Point Terminal (SRP) on the Bahamas.
The terminal has not been operational since 2019 due to
hurricane damages. On 21 February 2023 Equinor entered into an agreement for the sale
 
of the terminal to Liwathon.
Equinor UK holds an interest in the Aldbrough Gas Storage (Equinor: 33.3%) in the UK,
 
which is operated by SSE Hornsea Ltd.
Equinor Deutschland Storage GmbH holds an interest in the Etzel Gas Lager (Equinor: 28.7%)
 
in the north of Germany which has a
total of 19 caverns and secures regular gas deliveries from the NCS.
Equinor has ownership in a large number of oil and gas pipelines in the Norwegian upstream
 
oil and gas infrastructure system
including the largest joint venture Gassled (Equinor 5%).
Low carbon solutions
The Low Carbon Solutions (LCS) unit in MMP has responsibility for developing a profitable business
 
based on reforming natural gas
to hydrogen with carbon capture and storage (CCS) and to develop carbon management services to
 
offer industries based on CO
2
transport and storage. Decarbonising hydrocarbons with CCS is key to reaching net-zero, and Equinor
 
aims to combine its long
experience from CCS on the NCS, its reservoir expertise and experience from developing
 
value chains with peers, suppliers and
customers to develop large-scale, commercially-viable decarbonisation solutions. By 2030, more than
 
50% of Equinor’s Gross capex*
is intended to be dedicated to renewables and low carbon solutions. Below is
 
a list of key CCS and hydrogen projects.
Key projects
H2BE
Equinor, together with ENGIE, is developing the H2BE project in Belgium which aims to produce hydrogen from Norwegian
 
low-
carbon natural gas and applying carbon capture and storage (CCS). The project concept will apply
 
technology allowing for
decarbonization rates above 95% and will produce hydrogen at large (GW) scale at competitive
 
cost levels. The captured CO
2
 
is
planned to be transported by ship or offshore pipeline for permanent and safe storage at a site in the sub-surface
 
of the Norwegian
North Sea.
H2H Saltend
Equinor is developing
a proposed 600 MW hydrogen production plant, due to be operational by 2027 and
 
sited at
Saltend Chemicals Park in the UK, where it will help to reduce the park’s emissions by up to one third
 
(890,000 tonnes). To achieve
this, low carbon hydrogen will directly replace natural gas in several industrial facilities reducing
 
the carbon intensity of their products,
as well as being blended into natural gas at the Equinor and SSE Thermal’s on-site Triton power station. H2H Saltend is the
 
kick-
starter project for the wider Zero Carbon Humber scheme which aims to make the Humber, currently the UK’s most carbon intensive
industrial region, net-zero by 2040.
Northern Lights
 
Equinor is, together with Shell and TotalEnergies, developing infrastructure for transport and storage on the NCS of
CO
2
 
from various onshore industries. The approved development will have an initial storage capacity of around
 
1.5 million tonnes of
CO
2
 
per year, scalable to around 5 million tonnes of CO
2
 
per year. The Northern Lights infrastructure will enable transport of CO
2
 
from
industrial capture sites to a terminal in Øygarden for intermediate storage before transport
 
by pipeline for permanent storage in a
reservoir 2,600 metres under the seabed. In August 2022, Northern Lights and Yara signed the world’s first commercial agreement on
cross border CO
2
 
transport and storage. As part of the agreement, Northern Lights will transport and store CO
2
 
captured from Yara
Sluiskil, an ammonia and fertiliser plant in the Netherlands. The project is part of Longship,
 
the Norwegian authorities’ project for full-
scale carbon capture, transport and storage in Norway, and is expected to come on stream in 2024.
Smeaheia
 
Equinor was awarded by the Norwegian Ministry of Petroleum and Energy (MPE) the
 
operatorship for the development of
the CO
2
 
storage Smeaheia in the North Sea. Here, Equinor plans to develop enough the CO
2
 
storage capacity for 20 million tonnes of
CO
2
 
annually, which entails a sharp increase in the capacity to store CO
2
 
on the NCS. Smeaheia is expected to play an important role
in enabling CO
2
 
solutions on a commercial basis to industrial customers, such as steel, cement and other
 
heavy industries. Equinor
also has ambitions to develop further storage licences in the North Sea in the coming
 
years with the aim of building a common,
pipeline-based infrastructure that can contribute to substantial cost reductions for the CCS value
 
chains.
Performance review
Operational performance
exhibit154p147i1 exhibit154p147i0
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
147
Gas and Oil Sales.
The total natural gas sales volumes were 63 bcm in 2022, increased by 2 bcm
 
compared to total volumes for
2021. NCS equity gas volumes increased due to the recovery of Hammerfest LNG and due to efforts between EPN, MMP
 
and
authorities to increase gas export to Europe. This was achieved by increased production
 
permits, reduced gas injection and
optimization of NGL to increase gas calorific value. This was offset by a decrease in international equity gas.
The average crude, condensate and NGL sales were 2.0 mmbbl per day in 2022, slighty lower than
 
2021 mainly due to decrease in
volumes from NCS, partially offset by increase in sales of international equity volumes.
High regularity at onshore gas processing plants and transport systems ensured gas delivery reliability
 
and portfolio flexibility allowed
MMP to transport and sell natural gas and oil where it was most needed increasing value creation.
In 2022, the average invoiced natural gas sales price in Europe was USD 33.44 per mmBtu, up >100% from USD
 
14.60 per mmBtu in
2021. European gas prices were significantly higher compared to 2021, mainly due to high demand
 
and tight supply and caused by
reduced gas imports from Russia.
In 2022, the average invoiced natural gas sales price in North America was USD 5.89 mmBtu,
 
up 83% from USD 3.22 mmBtu in 2021.
North American gas price increase was driven by low production growth, low storage levels and
 
strong demand mainly from power
generation.
All of Equinor's gas produced on the NCS is sold by MMP and purchased from E&P
 
Norway at the fields’ lifting point at a market-
based internal price with deduction for the cost of bringing the gas from the field to the
 
market and a marketing fee element. Our NCS
transfer price for gas was USD 31.22 per mmBtu in 2022, an increase of 116% compared to USD 14.43 per mmBtu in 2021.
Throughput for Mongstad & Tjeldbergodden was lower in 2022 compared to 2021 mainly due to
 
higher planned and unplanned
shutdowns. MMP’s refining margins were higher for Mongstad in 2022 compared to 2021. Equinor's refining reference
 
margin
was 14,5 USD/bbl in 2022, compared to 4.0 USD/bbl in 2021, an increase of >100% due to due
 
to tight markets for products and
restriction imposed on the purchase of Russian products.
MMP - condensed income statement under IFRS
For the year ended 31 December
(in USD million)
2022
2021
Change
Revenues
147,691
87,204
69%
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
148
 
Equinor, Annual Report on Form 20-F 2022
 
Net income/(loss) from equity accounted investments
406
22
>100%
Other income
9
168
(95%)
Total revenues and other income
148,105
87,393
69%
Purchases [net of inventory]
(139,916)
(80,873)
73%
Operating, selling, general and administrative expenses
(4,591)
(3,753)
22%
Depreciation, amortisation and net impairment losses
14
(1,604)
N/A
Net operating income/(loss)
3,612
1,163
>100%
For the year ended 31 December
Operational information
2022
2021
Change
Liquid sales volume (mmbbl)
740.1
758.4
(2%)
Natural gas sales Equinor (bcm)
63.3
61.0
4%
Natural gas entitlement sales Equinor (bcm)
56.1
54.0
4%
Power generation (GWh) Equinor share
1,012
0
N/A
Average invoice gas price - Europe (USD/MMBtu)
33.44
14.60
>100%
Average invoice gas price - North America (USD/MMBtu)
5.89
3.22
83%
Financial performance
 
Net operating income
 
was USD 3,612 million compared to USD 1,163 million in 2021, an increase
 
of more than 100%.
The increase is explained by stronger results from gas, LNG and power sales trading activity, high clean spark spread and high
refining margin. The increase was partially offset by a negative change in derivatives used to manage
 
risk related to bilateral gas
sales contracts and from methanol production from natural gas.
 
Net operating income was positively impacted by an impairment reversal related to a refining asset and adjustments
 
for unrealized
market value of gas storages. This was offset by provisions, mainly for onerous contracts.
Total revenues and other income
 
were USD 148,105 million in 2022, compared to USD 87,393 million in 2021,
 
an increase of 69%.
The increase in
revenues
 
from 2022 to 2021 was mainly due to significant higher gas and oil sales prices in
 
both Europe and North
America, and higher gas volumes. This was partially offset by the negative effect of bilateral derivatives related to gas sales
agreements and slightly lower liquid sales.
Purchases [net of inventory]
 
were USD 139,916 million in 2022, compared to USD 80,873 million in 2021. The increase
 
from 2021
to 2022 was mainly due to higher prices for both gas and liquids.
Operating expenses and selling, general and administrative
expenses were USD 4,591 million in 2022, compared to USD 3,753
million in 2021. The increase from 2021 to 2022 was mainly due to significant higher transportation
 
costs for liquids and higher gas
and electricity prices affecting operating plants. This was partially offset by lower costs due to the sale of a refining asset.
 
Selling,
general and administrative expenses increased mainly due to increased activity within Low Carbon
 
Solutions and trading.
Depreciation, amortisation and net impairment
were positive USD 14 million in 2022, compared to negative USD 1,604 million in
2021. The decrease in depreciation, amortisation and net impairment losses from 2021 to
 
2022 was mainly caused by the impairment
of refinery assets in 2021 and reversal in 2022.
Balance sheet information:
 
The sum of equity accounted investments and non-current segment assets was USD
 
5,307 million for
the year ending 31 December 2022, compared to USD 4,119 million for the year ending 31 December 2021.
 
 
Equinor, Annual Report on Form 20-F 2022
 
149
3.4 Other group
The Other reporting segment includes activities in Projects, Drilling and Procurement (PDP), the
 
Technology,
 
Digital & Innovation
(TDI) segment and corporate staffs and support functions.
Overview
Technology,
 
Digital & Innovation (TDI)
Intending to strengthen the development of technologies, digital solutions and innovation, Equinor
 
has gathered the activities into a
business area, Technology,
 
Digital & Innovation (TDI).
 
TDI brings together research, technology development, specialist advisory services, digitisation, IT, improvement, innovation, ventures
and future business to one technology powerhouse. TDI is accountable for safe and efficient development
 
and operation of their
assets; and for providing expertise, projects and products across the company.
Corporate staff and support functions
Corporate staff and support functions comprise the non-operating activities supporting Equinor, and include head office and central
functions that provide business support such as finance and control, corporate communication, safety, security and sustainability,
corporate audit, legal and compliance and people and organisation.
Projects, Drilling & Procurement (PDP)
Projects, Drilling & Procurement (PDP) is responsible for oil and gas field development and well
 
delivery,
development of wind power,
CCS and hydrogen projects,
 
and procurement in Equinor.
 
PDP aims to deliver safe, secure and efficient project development,
including well construction, founded on world-class project execution and technology excellence.
 
PDP utilises innovative technologies,
digital solutions and carbon-efficient concepts to shape a competitive project portfolio at the forefront of the energy industry
transformation. Sustainable value is being created together with suppliers through a simplified and
 
standardised fit-for-purpose
approach.
Project development
 
is responsible for planning, developing and executing major oil and gas field development,
 
brownfield and field
decommissioning projects, and development and execution of wind power, CCS and hydrogen projects, where Equinor is the
operator.
Drilling and well
 
is responsible for designing wells and delivering drilling and well operations onshore
 
and offshore globally (except
for US onshore).
Procurement and supplier relations
 
is responsible for our global procurement activities and the management of supplier relations
with our extensive portfolio of suppliers.
Performance review
In 2022 the Other reporting segment recorded a net operating loss of USD 178 million compared
 
to a net operation loss of USD 234
million in 2021. The improvement was mainly due to reduced insurance costs during the
 
year relating to the fire at Melkøya LNG in
2020.
Since the implementation of IFRS 16 Leases in 2019, all leases were presented within
 
the Other segment and lease costs have been
allocated to the operating segments based on underlying lease payments with a corresponding
 
credit in the Other segment. With
effect from 2022, lease contracts are accounted for in accordance with IFRS 16 in all segments.
 
This change does not affect Equinor’s
consolidated financial statements. Comparative numbers in the segments have been restated.
Balance sheet information:
 
The sum of equity accounted investments and non-current segment assets was USD
 
1,096 million for
the year ending 31 December 2022, compared to USD 1,077 million for the year ending 31 December
 
2021.
 
 
 
 
150
 
Equinor, Annual Report on Form 20-F 2022
 
Financial
 
statements
and
 
notes
4.1
 
Consolidated financial statements
 
of the Equinor Group
4.2
 
Parent company financial statements
Equinor, Annual Report on Form 20-F 2022
 
151
4.1 Consolidated financial statements
 
of the Equinor group
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
152
 
Equinor, Annual Report on Form 20-F 2022
 
CONSOLIDATED STATEMENT
 
OF INCOME
Full year
(in USD million)
Note
2022
2021
2020
Revenues
7
149,004
88,744
45,753
Net income/(loss) from equity accounted investments
15
620
259
53
Other income
6
1,182
1,921
12
 
Total revenues and other income
7
150,806
90,924
45,818
 
Purchases [net of inventory variation]
 
(53,806)
(35,160)
(20,986)
Operating expenses
 
(9,608)
(8,598)
(8,831)
Selling, general and administrative expenses
 
(986)
(780)
(706)
Depreciation, amortisation and net impairment losses
12, 13
(6,391)
(11,719)
(15,235)
Exploration expenses
13
(1,205)
(1,004)
(3,483)
Total operating expenses
9
(71,995)
(57,261)
(49,241)
Net operating income/(loss)
5
78,811
33,663
(3,423)
Interest expenses and other finance expenses
(1,379)
(1,223)
(1,392)
Other financial items
1,172
(857)
556
Net financial items
10
(207)
(2,080)
(836)
 
Income/(loss) before tax
78,604
31,583
(4,259)
Income tax
11
(49,861)
(23,007)
(1,237)
Net income/(loss)
 
28,744
8,576
(5,496)
 
Attributable to equity holders of the company
 
28,746
8,563
(5,510)
Attributable to non-controlling interests
 
(3)
14
14
Basic earnings per share (in USD)
9.06
2.64
(1.69)
Diluted earnings per share (in USD)
9.03
2.63
(1.69)
Weighted average number of ordinary shares outstanding
 
(in millions)
3,174
3,245
3,269
Weighted average number of ordinary shares outstanding, diluted
 
(in millions)
3,183
3,254
3,277
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
153
CONSOLIDATED STATEMENT
 
OF COMPREHENSIVE INCOME
Full year
(in USD million)
Note
2022
2021
2020
Net income/(loss)
 
28,744
8,576
(5,496)
Actuarial gains/(losses) on defined benefit pension
 
plans
461
147
(106)
Income tax effect on income and expenses recognised
 
in OCI
1)
(105)
(35)
19
Items that will not be reclassified to the Consolidated
 
statement of income
22
356
111
(87)
Foreign currency translation effects
(3,609)
(1,052)
1,064
Share of OCI from equity accounted investments
424
0
0
Items that may subsequently be reclassified to the Consolidated
 
statement of income
(3,186)
(1,052)
1,064
Other comprehensive income/(loss)
(2,829)
(940)
977
Total comprehensive income/(loss)
25,914
7,636
(4,519)
Attributable to the equity holders of the company
25,917
7,622
(4,533)
Attributable to non-controlling interests
(3)
14
14
1) Other Comprehensive Income (OCI).
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
154
 
Equinor, Annual Report on Form 20-F 2022
 
CONSOLIDATED BALANCE SHEET
 
At 31 December
(in USD million)
Note
2022
2021
ASSETS
Property, plant and equipment
12
56,498
62,075
Intangible assets
13
5,158
6,452
Equity accounted investments
15
2,758
2,686
Deferred tax assets
11
8,732
6,259
Pension assets
22
1,219
1,449
Derivative financial instruments
28
691
1,265
Financial investments
16
2,733
3,346
Prepayments and financial receivables
16
2,063
1,087
Total non-current assets
 
79,851
84,618
Inventories
17
5,205
3,395
Trade and other receivables
1)
18
22,452
17,927
Derivative financial instruments
28
4,039
5,131
Financial investments
16
29,876
21,246
Cash and cash equivalents
2)
19
15,579
14,126
 
Total current assets
 
77,152
61,826
 
Assets classified as held for sale
6
1,018
676
Total assets
 
158,021
147,120
EQUITY AND LIABILITIES
Shareholders’ equity
 
53,988
39,010
Non-controlling interests
 
1
14
Total equity
20
53,989
39,024
Finance debt
21
24,141
27,404
Lease liabilities
25
2,409
2,449
Deferred tax liabilities
11
11,996
14,037
Pension liabilities
22
3,671
4,403
Provisions and other liabilities
23
15,633
19,899
Derivative financial instruments
28
2,376
767
Total non-current liabilities
 
60,226
68,959
Trade, other payables and provisions
24
13,352
14,310
Current tax payable
 
17,655
13,119
Finance debt
21
4,359
5,273
Lease liabilities
25
1,258
1,113
Dividends payable
20
2,808
582
Derivative financial instruments
28
4,106
4,609
Total current liabilities
 
43,539
39,005
 
Liabilities directly associated with the assets classified
 
as held for sale
6
268
132
Total liabilities
 
104,032
108,096
Total equity and liabilities
 
158,021
147,120
Equinor, Annual Report on Form 20-F 2022
 
155
1)
 
Of which Trade receivables of USD 17,334 million in 2022
 
and USD 15,237 million in 2021.
2)
 
Includes collateral deposits of USD 6,128 million
 
for 2022 related to certain requirements set out
 
by exchanges where Equinor is
participating. The corresponding figure for 2021 is
 
USD 2,069 million.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
156
 
Equinor, Annual Report on Form 20-F 2022
 
CONSOLIDATED STATEMENT
 
OF CHANGES IN EQUITY
(in USD million)
Share
capital
Additional
paid-in
capital
Retained
earnings
Foreign
currency
translation
reserve
OCI from equity
accounted
investments
1)
Shareholders'
equity
Non-
controlling
interests
Total equity
At 1 January 2020
1,185
7,732
37,481
(5,258)
0
41,139
20
41,159
Net income/(loss)
(5,510)
(5,510)
14
(5,496)
Other comprehensive income/(loss)
(87)
1,064
977
977
Total comprehensive income/(loss)
(4,519)
Dividends
(1,833)
(1,833)
(1,833)
Share buy-back
(21)
(869)
(890)
(890)
Other equity transactions
(11)
(11)
(15)
(25)
At 31 December 2020
1,164
6,852
30,050
(4,194)
0
33,873
19
33,892
Net income/(loss)
8,563
8,563
14
8,576
Other comprehensive income/(loss)
111
(1,052)
(940)
(940)
Total comprehensive income/(loss)
7,636
Dividends
(2,041)
(2,041)
(2,041)
Share buy-back
(429)
(429)
(429)
Other equity transactions
(15)
(15)
(18)
(33)
At 31 December 2021
1,164
6,408
36,683
(5,245)
0
39,010
14
39,024
Net income/(loss)
28,746
28,746
(3)
28,744
Other comprehensive income/(loss)
356
(3,609)
424
(2,829)
(2,829)
Total comprehensive income/(loss)
25,914
Dividends
(7,549)
(7,549)
(7,549)
Share buy-back
(22)
(3,358)
(3,380)
(3,380)
Other equity transactions
(10)
(10)
(10)
(20)
At 31 December 2022
1,142
3,041
58,236
(8,855)
424
53,988
1
53,989
1)
 
OCI items from equity accounted investments
 
that may subsequently be reclassified to the Consolidated
 
statement of income, are
presented as part of OCI from equity accounted
 
investments. OCI items that will not be reclassified
 
to the Consolidated statements of income
will be included in retained earnings.
 
Please refer to note 20 Shareholders’ equity
 
and dividends for more details.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
157
CONSOLIDATED STATEMENT
 
OF CASH FLOWS
Full year
(in USD million)
Note
2022
2021
2020
Income/(loss) before tax
78,604
31,583
(4,259)
Depreciation, amortisation and net impairment
12, 13
6,391
11,719
15,235
Exploration expenditures written off
13
342
171
2,506
(Gains)/losses on foreign currency transactions and
 
balances
(2,088)
(47)
646
(Gains)/losses on sale of assets and businesses
6
(823)
(1,519)
18
(Increase)/decrease in other items related to operating
 
activities
1)
468
106
918
(Increase)/decrease in net derivative financial instruments
28
1,062
539
(451)
Interest received
399
96
162
Interest paid
(747)
(698)
(730)
Cash flows provided by operating activities before
 
taxes paid and working capital items
83,608
41,950
14,045
Taxes paid
(43,856)
(8,588)
(3,134)
(Increase)/decrease in working capital
(4,616)
(4,546)
(524)
Cash flows provided by operating activities
 
35,136
28,816
10,386
Capital expenditures and investments
6
(8,611)
(8,151)
(8,476)
(Increase)/decrease in financial investments
(10,089)
(9,951)
(3,703)
(Increase)/decrease in derivative financial instruments
1,894
(1)
(620)
(Increase)/decrease in other interest-bearing items
(23)
28
202
Proceeds from sale of assets and businesses
6
966
1,864
505
Cash flows provided by/(used in) investing activities
(15,863)
(16,211)
(12,092)
New finance debt
21
0
0
8,347
Repayment of finance debt
21
(250)
(2,675)
(2,055)
Repayment of lease liabilities
25
(1,366)
(1,238)
(1,277)
Dividends paid
20
(5,380)
(1,797)
(2,330)
Share buy-back
20
(3,315)
(321)
(1,059)
Net current finance debt and other financing activities
(5,102)
1,195
1,365
Cash flows provided by/(used in) financing activities
21
(15,414)
(4,836)
2,991
Net increase/(decrease) in cash and cash equivalents
3,860
7,768
1,285
Foreign currency translation effects
(2,268)
(538)
294
Cash and cash equivalents at the beginning of
 
the period (net of overdraft)
19
13,987
6,757
5,177
Cash and cash equivalents at the end of the period
 
(net of overdraft)
2)
19
15,579
13,987
6,757
1)
 
The line item mainly consists of provisions, unrealised
 
gains and losses and items of income
 
or expense for which the cash effects are
included in increase/(decrease) in working capital within
 
operating cash flow and investing cash flows.
 
The line item includes a fair value
loss related to inventory of USD 672 million
 
at 31 December 2022.
 
Amount for 2021 includes MUSD (822) redetermination
 
settlement for
the Agbami field.
 
2)
 
At 31 December 2022 cash and cash equivalents
 
net overdraft was zero. At 31 December 2021
 
cash and cash equivalents included a net
overdraft of USD 140 million and at 31 December
 
2020 net overdraft were zero.
Interest paid
in cash flows provided by operating activities
 
excludes capitalised interest of USD 382 million, USD
 
334 million, and USD 308
million for the years ending 31 December 2022, 2021
 
and 2020, respectively. Capitalised interest is included in Capital expenditures
 
and
investments in cash flows used in investing activities.
 
Total interest paid amounts to USD 1,129 million, USD 1,032 million, and USD 1,038
million for the years 2022, 2021 and 2020, respectively.
 
 
 
 
158
 
Equinor, Annual Report on Form 20-F 2022
 
Notes to the Consolidated financial statements
Table of contents for notes to the financial statements
1
Organisation
2
Accounting policies
3
Consequences of initiatives to limit climate changes
4
Financial risk and capital management
5
Segments
6
Acquisitions and disposals
7
Total revenues and other income
8
Salaries and personnel expenses
9
Auditor’s remuneration and Research and development expenditures
10
Financial items
11
Income taxes
12
Property, plant and equipment
13
Intangible assets
14
Impairments
15
Joint arrangements and associates
16
Financial investments and financial receivables
17
Inventories
18
Trade and other receivables
19
Cash and cash equivalents
20
Shareholders’ equity and dividends
21
Finance debt
22
Pensions
23
Provisions and other liabilities
24
Trade, other payables and provisions
25
Leases
26
Other commitments, contingent liabilities and contingent assets
27
Related parties
28
Financial instruments and fair value measurement
29
Subsequent events
Equinor, Annual Report on Form 20-F 2022
 
159
1 Organisation
The Equinor Group (Equinor) consists of Equinor ASA and its subsidiaries. Equinor ASA
 
is incorporated and domiciled in Norway and
listed on the Oslo Børs (Norway) and the New York Stock Exchange (USA). The address of its registered office is Forusbeen 50, N-
4035 Stavanger, Norway.
Equinor’s objective is to develop, produce and market various forms of energy and
 
derived products and services, as well as other
business. The activities may also be carried out through participation in or cooperation with other
 
companies. Equinor Energy AS, a
100% owned operating subsidiary of Equinor ASA and owner of all of Equinor's oil and gas
 
activities and net assets on the Norwegian
continental shelf, is co-obligor or guarantor for certain debt obligations of Equinor ASA.
The Consolidated financial statements of Equinor for the full year 2022 were approved for issuance
 
by the board of directors on 14
March 2023 and is subject to approval by the annual general meeting on 10 May 2023.
2 Accounting policies
Statement of compliance
The Consolidated financial statements of Equinor ASA and its subsidiaries (Equinor) have been
 
prepared in accordance with
International Financial Reporting Standards (IFRS) as adopted by the European Union (EU) and
 
with IFRSs as issued by the
International Accounting Standards Board (IASB), interpretations issued by IASB and the additional
 
requirements of the Norwegian
Accounting Act, effective on 31 December 2022.
Basis of preparation
The Consolidated financial statements are prepared on the historical cost basis with some exceptions where fair
 
value measurement
is applied. These exceptions are specifically disclosed in the accounting policies sections in relevant notes. The
 
material accounting
policies described in these Consolidated financial statements have been applied consistently to all periods presented,
 
except as
otherwise noted in the disclosure related to the impact of policy changes following the
 
adoption of new accounting standards and
voluntary changes in 2022.
Certain amounts in the comparable years have been restated or reclassified to conform to current
 
year presentation. All amounts in
the Consolidated financial statements are denominated in USD millions, unless otherwise specified. The subtotals and totals
 
in some
of the tables in the notes may not equal the sum of the amounts shown in the primary
 
financial statements due to rounding.
Operational expenses in the Consolidated statement of income are presented as a combination
 
of function and nature in conformity
with industry practice. Purchases [net of inventory variation] and Depreciation, amortisation and
 
net impairment losses are presented
on separate lines based on their nature, while Operating expenses and Selling, general
 
and administrative expenses as well as
Exploration expenses are presented on a functional basis. Significant expenses such as salaries, pensions,
 
etc. are presented by their
nature in the notes to the Consolidated financial statements.
Basis of consolidation
The Consolidated financial statements include the accounts of Equinor ASA and its subsidiaries
 
as well as Equinor’s interests in jointly
controlled and equity accounted investments. All intercompany balances and transactions, including unrealised
 
profits and losses
arising from Equinor's internal transactions, have been eliminated.
The Consolidated financial statements include all entities controlled by Equinor ASA. Entities
 
are determined to be controlled by
Equinor when Equinor has power over the entity, ability to use that power to affect the entity's returns, and exposure to, or rights to,
variable returns from its involvement with the entity. The financial statements of the subsidiaries are included in the Consolidated
financial statements from the date control is achieved until the date control ceases.
Non-controlling interests are presented separately within equity in the Consolidated balance sheet.
Foreign currency translation
In preparing the financial statements of the individual entities in Equinor, transactions in currencies other than the functional currency
are translated at the foreign exchange rate at the dates of the transactions. Monetary
 
assets and liabilities denominated in foreign
currencies are translated to the functional currency at the foreign exchange rate at the balance
 
sheet date. Foreign exchange
differences arising on translation are recognised in the Consolidated statement of income as foreign exchange
 
gains or losses within
Net financial items. However, foreign exchange differences arising from the translation of estimate-based provisions are generally
accounted for as part of the change in the underlying estimate and included within the
 
relevant operating expense or income tax line-
160
 
Equinor, Annual Report on Form 20-F 2022
 
items depending on the nature of the provision. Non-monetary assets measured at historical cost
 
in a foreign currency are translated
using the exchange rate at the date of the transactions.
When preparing the Consolidated financial statements, the assets and liabilities of entities with functional
 
currencies other than the
Group’s presentation currency USD are translated into USD at the foreign exchange rate at the balance
 
sheet date. The revenues
 
and
expenses of such entities are translated using the foreign exchange rates on the dates of the
 
transactions. Foreign exchange
differences arising on translation from functional currency to USD are recognised separately in the
 
Consolidated statement of
comprehensive income within Other comprehensive income (OCI). The cumulative amount of such
 
translation differences relating to
an entity is reclassified to the Consolidated statement of income and reflected as a part of
 
the gain or loss on disposal of that entity.
Loans from Equinor ASA to subsidiaries and equity accounted investments with other functional
 
currencies than the parent company,
and for which settlement is neither planned nor likely in the foreseeable future, are considered part
 
of the parent company’s net
investment in the subsidiary. Foreign exchange differences arising on such loans are recognised in OCI in the Consolidated financial
statements.
Statement of cash flows
In the statement of cash flows, operating activities are presented using the indirect method, where Income/(loss)
 
before tax is adjusted
for changes in inventories and operating receivables and payables, the effects of non-cash items such as depreciations,
 
amortisations
and impairments, provisions, unrealised gains and losses and undistributed profits from associates, and items
 
of income or expense
for which the cash effects are investing or financing cash flows. Increase/decrease in financial investments, Increase/decrease
 
in
derivative financial instruments, and Increase/decrease in other interest-bearing items are all presented
 
net as part of Investing
activities, either because the transactions are financial investments and turnover is quick, the amounts
 
are large, and the maturities
are short, or due to materiality.
--------------------------------------------------------------------------------------------------------------------------------
Accounting judgement and key sources of estimation uncertainty
The preparation of the Consolidated financial statements requires management to make accounting
 
judgements, estimates and
assumptions affecting reported amounts of assets, liabilities, income and expenses.
The main areas where Equinor has made significant judgements
 
when applying the accounting policies and that have the most
material effect on the amounts recognised in the Consolidated financial statements have been described in the
 
following notes:
6 – Acquisitions and disposals
7 – Total revenues and other income
25 – Leases
Estimates used in the preparation of these Consolidated financial statements are prepared based on customised models,
 
while the
assumptions on which the estimates are based rely on historical experience, external sources of information
 
and various other factors
that management assesses to be reasonable under the current conditions and circumstances. These
 
estimates and assumptions form
the basis of making the judgements about carrying values of assets and liabilities
 
when these are not readily apparent from other
sources. Actual results may differ from these estimates. The estimates and underlying assumptions are reviewed on an on-going
basis considering the current and expected future set of conditions.
Equinor is exposed to several underlying economic factors affecting the overall results, such as commodity prices,
 
foreign currency
exchange rates, market risk premiums and interest rates as well as financial instruments with
 
fair values derived from changes in
these factors. The effects of the initiatives to limit climate changes and the potential impact of the energy transition
 
are relevant to
several of these economic assumptions. In addition, Equinor's results are influenced by the level
 
of production, which in the short term
may be influenced by, for instance, maintenance programmes. In the long-term, the results are impacted by the success of
exploration, field developments and operating activities.
The most important matters in understanding the key sources of estimation uncertainty
 
are described in each of the following notes:
3 – Consequences of initiatives to limit climate changes
11 – Income taxes
12 – Property, plant and equipment
13 – Intangible assets
14 – Impairments
23 – Provisions and other liabilities
26 – Other commitments, contingent liabilities and contingent assets
--------------------------------------------------------------------------------------------------------------------------------
Changes in accounting policies in the current period
Amendments to IAS 1 and IFRS practice statement 2: Replacing Significant accounting policies with Material
 
accounting
policies
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
161
IASB has issued amendments to IAS 1 Presentation of financial statements and IFRS
 
Practice Statement 2 Making Materiality
Judgements. These amendments are intended to help entities apply materiality judgements to accounting
 
policy disclosures and
provide additional guidance and illustrative examples. The amendments are effective for annual periods beginning on or
 
after 1
January 2023. Earlier application is permitted, and Equinor has applied the amendments with
 
effect from these Consolidated financial
statements.
Accounting policy information should be considered material if its disclosure can reasonably be
 
expected to influence user decisions
and therefore is needed to understand other information provided about material transactions, other
 
events, or conditions in the
financial statements. IASB has acknowledged that standardised information, or information that only duplicates
 
or summarises the
requirements of the IFRS -standards, is generally less useful than entity-specific accounting policy information.
 
Even though such
information could be material in specific circumstances, Equinor has focused the accounting policy disclosures
 
on Equinor-specific
policy choices, disclosing only those accounting policies that are considered necessary to understand other material
 
information in the
Consolidated financial statements of Equinor.
Other standards, amendments to standards and interpretations of standards, effective
 
as of 1 January 2022
Other amendments to standards or interpretations of standards effective as of 1 January 2022 and adopted by Equinor, were not
material to Equinor’s Consolidated financial statements upon adoption.
Other standards, amendments to standards, and interpretations of standards, issued but not yet effective, are either
 
not expected to
materially impact, or are not expected to be relevant to, Equinor's Consolidated financial statements
 
upon adoption.
3 Consequences of initiatives to limit climate changes
Accounting policies - c
ost of CO
2
 
quotas
Purchased CO
2
 
quotas under the EU Emissions Trading System (EU ETS) are reflected at cost in Operating expenses as
incurred in line with emissions. Accruals for CO
2
 
quotas required to cover emissions to date are valued at market price and
reflected as a current liability within Trade, other payables and provisions. Quotas owned, but exceeding the emissions
incurred to date, are carried in the balance sheet at cost price, classified as Other current receivables, as long as such
purchased quotas are acquired in order to cover own emissions and may be kept to cover subsequent years’ emissions.
Quotas purchased and held for trading purposes are carried in the balance sheet at fair value, and the changes in fair value
are reflected in the Consolidated statement of income on the line-item Other income.
Obligations resulting from current year emissions and the corresponding amounts for quotas that have been bought, paid and
expensed, but which have not yet been surrendered to the relevant authorities, are reflected net in the balance sheet.
 
----------------------------------------------------------------------------------------------------------------------------------------
Equinor’s strategy and ambitions
Equinor’s ambition is to continue supplying society with energy with lower emissions
 
over time, to be a leading company in the energy
transition and becoming a net-zero company by 2050, including emissions from production through to final
 
energy consumption.
Equinor’s strategy is to create value as a leader in the energy transition by pursuing
 
high-value growth in renewables and new market
opportunities in low carbon solutions at the same time as we optimise our oil and gas portfolio.
 
This strategy covers three strategically
important and interconnected areas:
●
 
Oil and gas. Equinor’s main focus is optimising our resources, cutting emissions in
 
our operations and identifying new procedures
that enable us to continue supplying energy that the world needs with a low footprint.
●
 
Renewables. There is an apparent global demand for more renewable energy, and Equinor’s investments in offshore wind and
solar are growing exponentially to meet this demand.
●
 
Low carbon solutions. Equinor will continue its investments in new technologies and value chains
 
for producing lower emissions
by replacing the use of carbon when generating new energy or capturing and removing the greenhouse
 
gases before they reach
the atmosphere. Even though carbon capture and storage (CCS) has existed as a technology for many decades,
 
it takes time to
develop the value chains and carbon capture and storage has yet to be implemented
 
as a revenue-generating service to the
market on a full scale.
Risks arising from climate change and the transition to a lower carbon economy
Policy, legal, regulatory,
 
market and technology developments related to the issue of climate change, can affect our business plans
and financial performance. Shifts in stakeholder focus between energy security, affordability and sustainability add uncertainty to
delivery and outcomes associated with Equinor’s strategy. Equinor’s long-term plans have to consider how the global
 
energy markets
may develop in the long term. Potential scenarios of future changes in demand for our products
 
(oil, gas and power in key markets)
are analysed, including World Energy Outlook 2022 (WEO) scenarios that illustrate the wide range of
 
possible demand for different
 
 
 
 
 
 
 
 
 
 
 
162
 
Equinor, Annual Report on Form 20-F 2022
 
energy sources, including fossil fuels, nuclear and renewables. Commodity price sensitivities are presented in a table below
 
and in
note 14 Impairments.
Equinor assesses climate risk from two perspectives: transition risk, which relates to the financial robustness of the
 
company’s
business model and portfolio in various decarbonisation scenarios; and physical climate risk, which relates
 
to the exposure of our
assets to climate-related perils in different warming scenarios. Equinor’s climate roadmap and all of our
 
climate-related ambitions are
a response to these challenges and risks related to climate change.
●
 
Stricter climate laws, regulations and policies as well as adverse litigation outcomes could adversely impact Equinor's
 
financial
results and outlook, including the value of its assets. This might be directly through regulatory
 
changes towards energy systems
free of unabated fossil fuels, changes in taxation, increased costs, access to opportunities, or indirectly
 
through changes in
consumer behaviour or technology developments.
 
●
 
Changing demand for renewable energy and low-carbon technologies, and innovation and technology
 
changes supporting their
cost-competitive development, represent both threats and opportunities for Equinor. We assess and manage climate-related risks
related to technology development and implementation across our portfolio, as well as recognising
 
risks related to competing or
emerging technologies elsewhere. Examples of relevant technologies within our portfolio include
 
carbon capture and storage
(CCS), blue/green hydrogen, battery technology, solar and wind renewable energy, nuclear fusion, low CO
2
 
intensity solutions,
improvements in methane emissions and application of renewables in oil and gas production.
●
 
Market development and our ability to reduce costs and capitalize on technology improvements
 
are important but unpredictable
risk factors. Multiple factors in the energy transition contribute to uncertainty in future energy price
 
assumptions, and changes in
investor and societal sentiment can affect our access to capital markets, attractiveness for investors, and potentially
 
restrict
access to finance or increase financing costs.
●
 
Strong competition for assets, changing levels of policy support, and different commercial/contractual models
 
may lead to
diminishing returns within the renewable and low carbon industries and hinder Equinor
 
ambitions. These investments may be
exposed to interest rate risk and inflation risk.
●
 
Changes in physical climate parameters could impact Equinor through increased costs or incidents affecting Equinor’s
operations. Examples of acute physical parameters that could impact Equinor’s facility
 
design and operations include increasing
frequency and severity of extreme weather events such as extreme windspeeds, wave-heights
 
or flooding. Examples of chronic
physical climate parameters include limitations in freshwater availability, a pattern with generally increased wind speeds and as
most of Equinor’s physical assets are located offshore, a key potential chronic physical climate impact
 
is expected to be rising
sea level accompanied with increased wave heights. As we continue to build our renewable
 
portfolio, unexpected changes in
meteorological parameters, such as average wind speed or changes in wind patterns and
 
cloud cover that affect renewable
energy production will also be important factors to consider. Physical risk factors are mitigated through technical and engineering
functions in design, operations and maintenance, with due consideration of how the external
 
physical environment may be
changing. However, there is uncertainty regarding the magnitude of impact and time horizon for the occurrence of physical
impacts of climate change, which leads to uncertainty regarding the potential impact for Equinor.
Impact on Equinor’s financial statements
CO
2
-cost and EU ETS carbon credits
Our oil & gas operations in Europe are part of the EU Emission Trading Scheme (EU ETS). Equinor buys EU
 
ETS allowances (quotas
or carbon credits) for the emissions related to our oil & gas production and processing. Currently
 
we receive a share of free quotas
according to the EU ETS regulation. The share of free quotas is expected to be significantly
 
reduced in the future.
Total expensed CO
2
 
cost related to emissions and purchase of CO
2
quotas in Equinor related to activities resulting in GHG emissions
(Equinor’s share of the operating licences in addition to our land-based facilities)
 
amounts to USD 510 million in 2022, USD 428
million in 2021, and USD 268 million in 2020. A large portion of the cost of CO
2
 
in Equinor is related to the purchase of EU ETS
quotas. The table below shows an analysis of number of quotas utilised by Equinor’s
 
operated licences and land-based facilities
subject to the requirements under EU ETS:
Number of EU ETS quotas
2022
2021
Opening balance at 1 January
11,026,286
11,027,242
Allocated free quotas
3,697,089
3,560,286
Purchased quotas on the ETS market
5,985,000
7,605,265
Sold quotas on the ETS market
0
(135,177)
Settled quotas (offset against emissions)
(9,925,999)
(11,031,330)
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
163
Closing balance at 31 December
10,782,376
11,026,286
Investments in renewables
The energy transition creates many new business opportunities, primarily related to further
 
development of Equinor’s renewables
business and within CCS. Driven by the energy transition and an increasing demand for
 
electricity from renewable energy sources,
Equinor continues to build its renewable business. We focus on offshore wind and also explore opportunities within onshore
renewables and integrated power market solutions. At present, Equinor’s renewable portfolio spans
 
multiple continents and
technologies– onshore and offshore – and different ownership structures:
●
 
In operation: Mainly offshore wind in UK and Germany and solar farms in Brazil and Argentina
●
 
In construction: The most significant projects are the Dogger Bank projects in UK (SSE
 
operated) and Hywind Tampen in Norway
in addition to construction of solar plants in Poland
●
 
Additional capacity has secured offtake, mainly offshore wind projects in the US and Poland
●
 
Accessed pipeline capacity (currently without offtake). This includes offshore wind in the US and South Korea and
 
solar and
onshore wind projects in Brazil and Poland
●
 
Equinor also holds a 13.1% shareholding in Scatec ASA, a leading renewable power producer, delivering affordable and clean
energy worldwide
Equinor’s investments in renewables and low carbon solutions projects are included as Additions
 
to PP&E, intangibles and equity
accounted investments in the REN-segment in note 5 Segments and amounts to USD
 
298 million in 2022 and USD 457 million in
2021. Equinor's ambition is to become a global offshore wind major and an industry leader in floating
 
offshore wind, drawing on our
extensive offshore experience to drive the industry forward. In addition, Equinor explores opportunities within
 
onshore renewables.
Investments in CCS
Through our activities within CCS, we are building capabilities and a competitive position for future business
 
opportunities and a new
revenue stream related to disposal of CO
2
 
from customers such as from waste incineration and cement production and would also be
basis for solutions for decarbonised hydrogen as an energy carrier which would also be a flexible
 
solution to backup intermittent
renewables in Europe. Equinor is making significant steps to industrialise CCS and we
 
are already involved in the Northern Lights
project in Norway providing CO
2
 
transport and storage solutions (in partnership with Shell and TotalEnergies). It represents the start of
commercial CCS in Europe and is on track to demonstrate that CCS is a valid decarbonisation solution
 
for important industry sectors.
Equinor has during 2022 contributed with USD 36 million to the company as capital increases
 
(USD 21 million in 2021).
Research and development activities (R&D)
In addition to the beforementioned significant financial effects, Equinor is also involved in several activities within
 
R&D. Several of
these activities are related to optimising our oil and gas activities and cutting emissions from our
 
activities as well as developing new
business opportunities within renewables or low carbon solutions. Financial effects from Equinor’s total
 
R&D activities can be located
in note 9 Auditor’s remuneration and Research and development expenditures
 
(expensed R&D) and in note 12 Property, Plant &
Equipment (capitalised R&D).
Effects on estimation uncertainty
The effects of the initiatives to limit climate changes and the potential impact of the energy transition
 
are relevant to some of the
economic assumptions in our estimations of future cash flows. The results of the development
 
of such initiatives, and the degree to
which Equinor’s operations will be affected by them, are sources of uncertainty. Estimating global energy demand and commodity
prices towards 2050 is a challenging task, as this comprises assessing the future development
 
in supply and demand, technology
change, taxation, tax on emissions, production limits and other important factors. The assumptions
 
may change over time, which
could materialise in different outcomes from the current projected scenarios. This could result in significant changes
 
to accounting
estimates, such as economic useful life (affects depreciation period and timing of asset retirement obligations), value-in-use
calculations (affects impairment assessments) and measurement of deferred tax assets.
Commodity prices
Equinor’s commodity price assumptions applied in value-in-use impairment testing, are
 
set in accordance with requirements in IFRS
and based on management’s best estimate of the development of relevant current circumstances and the likely
 
future development of
such circumstances. This price-set is currently not equal to a price-set required to achieve
 
the goals in the Net Zero Emissions (NZE)
by 2050 Scenario, nor a price-set in accordance with the Announced Pledges Scenario as
 
defined by the International Energy Agency
(IEA). A future change in the trajectory of how the world acts with regards to implementing
 
actions in accordance with the goals in the
Paris agreement could, depending on the detailed characteristics of such a trajectory, have a negative impact on the valuation of
Equinor’s property, plant and equipment in total. A calculation of a possible effect of using the assumed commodity prices and CO
2
prices in a 1.5
o
C compatible NZE by 2050 Scenario as estimated by IEA could result
 
in an impairment of upstream production assets
and intangible assets around USD 4 billion before tax, see the sensitivity table below.
Similarly, we have calculated the possible effect of using prices according to the Announced Pledges Scenario, a scenario which is
based on all of the climate-related commitments announced by governments around the Globe.
 
Using this scenario, the world is
 
 
 
 
 
 
 
 
 
 
164
 
Equinor, Annual Report on Form 20-F 2022
 
expected to reach a 1.8
o
C increase in the year 2100, and this could result in an impairment of less than USD
 
0.5 billion before tax
using the same simplified model, see the sensitivity table below.
These illustrative impairment sensitivity calculations are based on a simplified model and limitations
 
described in note 14 Impairments.
However, when preparing these illustrative scenario sensitivities, we have linearly interpolated between current prices and the price
set disclosed in the table below for both the NZE by 2050 scenario and the Announced
 
pledges scenario. Applying this simplified
approach, the illustrative potential impairments are significantly lower than the amount disclosed in note 14 Impairments
 
where an
immediate 30% reduction in commodity prices has been applied, also considering a somewhat
 
declining production profile,
concentrated before the year 2030 for our producing and sanctioned development projects and the effects of discounting.
Cost of CO
2
The EU ETS price has increased significantly from 25 EUR/tonne in 2020. The average cost
 
of EU ETS allowances was 81
EUR/tonne in 2022 (54 EUR/tonne in 2021). The price is expected to remain high,
 
in the region of 80 EUR/tonne for the next couple of
years. Then the price is expected to be 105 EUR/tonne in 2040 and thereafter increasing
 
to 130 EUR/tonne in 2050. As such, Equinor
expects greenhouse gas emission costs to increase from current levels and to have
 
a wider geographical range than today, and a
global tax on CO
2
 
emissions will have a negative impact on the valuation of Equinor’s oil and gas
 
assets. Currently, Equinor pays CO
2
fees in Norway, the UK, Germany and Nigeria. Norway’s Climate Action Plan for the period 2021-2030 (Meld. St 13 (2020-2021))
which assumes a gradually increased CO
2
 
tax (the total of EU ETS + Norwegian CO
2
 
tax) in Norway to 2,000 NOK/tonne in 2030 is
used for impairment calculations of Norwegian upstream assets.
Equinor’s response to this risk is evaluation of carbon intensity on both project
 
and portfolio level in our investment and divestment
decisions. We have also introduced an internal carbon price, currently set at 58 USD/tonne and increasing towards 100 USD/tonne
 
by
the year 2030 and staying flat thereafter (in countries with higher carbon costs, we use the
 
country specific cost expectations), to be
used in our investment decisions. This cost-scenario is uncertain, but this extra cost serves
 
as a placeholder for possible future CO
2
pricing systems, making sure our assets are financially robust in such a scenario. As such, climate
 
considerations are a part of the
investment decisions following Equinor’s strategy and commitments to the
 
energy transition.
Climate considerations are also included in the impairment calculations directly by estimating the CO
2
 
taxes in the cash flows.
Indirectly, the expected effect of climate change is included in the estimated commodity prices where supply and demand are
considered. The CO
2
 
prices also have effect on the estimated production profiles and economic cut-off of the projects. Impairment
calculations are based on best estimate assumptions. To reflect that carbon will have a cost for all our assets, the current best
estimate is considered to be EU ETS for countries outside EU where carbon is not already
 
subject to taxation or where Equinor has
not established specific estimates.
Sensitivity table
In this table, we have presented some relevant prices and variables and the anticipated future development
 
compared to our
managements’ best estimate and an illustrative potential impairment effect given these scenarios. The scenario price-sets have
 
been
retrieved from IEA’s report, World Energy Outlook 2022. Prices are adjusted for inflation and presented in Real 2022. USD 2 per bbl of
transportation cost has been added to the brent-prices in the scenarios for comparability
 
with our current best estimate:
Management's price
assumptions
1)
NZE by 2050 scenario
Announced Pledged Scenario
Brent blend, 2030
75
USD/bbl
40
USD/bbl
71
USD/bbl
Brent blend, 2040
70
USD/bbl
34
USD/bbl
69
USD/bbl
Brent blend, 2050
65
USD/bbl
28
USD/bbl
67
USD/bbl
TTF, 2030
9.5
USD/MMBt
u
5.0
USD/MMBtu
8.5
USD/MMBt
u
TTF, 2040
9.0
USD/MMBt
u
4.5
USD/MMBtu
7.7
USD/MMBt
u
TTF, 2050
9.0
USD/MMBt
u
4.1
USD/MMBtu
6.8
USD/MMBt
u
EU ETS
2), 3)
, 2030
94
USD/tCO
2
152
USD/tCO
2
146
USD/tCO
2
EU ETS
2), 3)
, 2040
124
USD/tCO
2
222
USD/tCO
2
189
USD/tCO
2
EU ETS
2), 3)
, 2050
153
USD/tCO
2
271
USD/tCO
2
216
USD/tCO
2
Illustrative potential impairment (USD)
~
4.0
billion
<
0.5
billion
1)
 
Management’s future commodity price assumptions applied
 
when estimating value in use, see note 14 Impairments
2)
 
Scenarios: Price of CO
2
 
quotas in advanced economies with net zero pledges,
 
not including any other CO
2
 
taxes
3)
 
EU ETS price assumptions have been translated from EUR
 
to USD using Equinor’s assumptions for currency rates, EUR/USD
 
= 1,176
Robustness of our upstream oil & gas portfolio, and risk of stranded assets
The transition to renewable energy, technological development and the expected reduction in global demand for carbon-based
energy, may have a negative impact on the future profitability of investments in upstream oil and gas assets, in particular assets with
long estimated useful lives, projects in an early development phase and undeveloped assets
 
controlled by Equinor. Equinor uses
 
 
Equinor, Annual Report on Form 20-F 2022
 
165
scenario analysis to outline different possible energy futures and several of these imply lower oil and natural gas
 
prices. If they
decrease, the oil and gas revenues will also decrease, and potentially reduce the economic
 
lifetime of some assets. Equinor seeks to
mitigate this risk by focusing on improving the resilience of the existing upstream portfolio, maximising the
 
efficiency of our
infrastructure on the Norwegian Continental Shelf and optimising our high-quality international portfolio. Equinor
 
will continue to add
high value barrels to the portfolio through exploration and increased recovery, and NCS cash flow and value creation are expected to
remain high also beyond 2030. The NCS project portfolio is very robust against potential low
 
oil and gas prices and actions are in
place to both maintain cost discipline across the company and ensure robustness of the non-sanctioned oil
 
and natural gas projects.
Equinor will also continue to selectively explore for new resources with a focus on mature
 
areas with existing infrastructure to minimise
emissions and maximise value. During the transition, Equinor anticipates allocating a smaller share of
 
our capital expenditure to oil
and gas in the coming years and the volume of production is likely to decrease
 
over time. Reaching our 50 percent reduction ambition
for operated scope 1 and 2 emissions will require a focused and coordinated effort across the company
 
on executing and maturing
abatement projects, improving energy efficiency of offshore and onshore assets, developing new technologies, and strengthening
resilience in the portfolio. The abatement projects primarily include electrification of offshore assets in Norway, mainly by power from
shore but also including innovations such as Hywind Tampen, our floating wind farm powering offshore oil and gas platforms. In
combination with our focus on renewables and CCS, these abatement projects are expected to
 
reduce Equinor’s emissions
sufficiently to support our mid-term ambitions. As such, Equinor’s plans to become
 
a net-zero company by 2050 have currently not
resulted in the identification of additional assets being triggered for impairment or earlier cessation.
Any future exploration may be restricted by regulations, market and strategic considerations. Provided
 
that the economic assumptions
would deteriorate to such an extent that undeveloped assets controlled by Equinor should not materialize,
 
assets at risk mainly
comprise the intangible assets Oil and Gas prospects, signature bonuses and the capitalised exploration
 
costs, with a total carrying
value of USD 3,634 million. See note 13 Intangible assets for more information regarding Equinor’s
 
intangible assets.
Timing of Asset Retirement Obligations (ARO)
As mentioned above, there are currently no assets triggered for earlier cessation as a result
 
of Equinor’s plans to become a net-zero
company by 2050. But, if the business cases of Equinor’s oil and gas
 
producing assets in the future should change materially due to
governmental initiatives to limit climate change, this could affect the timing of cessation of our assets and
 
also our asset retirement
obligations. A shorter production period, accelerating the time for when assets need to be removed
 
after ended production, will
increase the carrying value of the liability. To
 
illustrate the potential financial effect of earlier removal, we have estimated the effect of
performing removal five years earlier than currently scheduled to an increase in the liability of
 
around USD 1 billion. See note 23
Provisions and other liabilities for more information regarding Equinor’s ARO.
4 Financial risk and capital management
General information and financial risks
Equinor's business activities naturally expose Equinor to financial risks such as market risk (including
 
commodity price risk, currency
risk, interest rate risk and equity price risk), liquidity risk and credit risk. Equinor’s approach
 
to risk management includes assessing
and managing risk in activities using a holistic risk approach, by considering relevant correlations at portfolio
 
level between the most
important market risks and the natural hedges inherent in Equinor’s portfolio. This
 
approach allows Equinor to reduce the number of
risk management transactions and avoid sub-optimisation.
The corporate risk committee, which is headed by the chief financial officer, is responsible for Equinor’s Enterprise Risk Management
and for proposing appropriate measures to adjust risk at the corporate level. This includes assessing
 
Equinor’s financial risk policies.
Market risk
Equinor operates in the worldwide crude oil, refined products, natural gas, and electricity markets
 
and is exposed to market risks
including fluctuations in hydrocarbon prices, foreign currency rates, interest rates, and electricity
 
prices that can affect the revenues
and costs of operating, investing, and financing. These risks are managed primarily on a short-term basis with
 
a focus on achieving
the highest risk-adjusted returns for Equinor within the given mandate. Long-term exposures
 
are managed at the corporate level,
while short-term exposures are managed according to trading strategies and mandates. Mandates in
 
the trading organisations within
crude oil, refined products, natural gas,
 
and electricity are relatively restricted compared to the total market risk of Equinor.
Commodity price risk
Equinor’s most important long-term commodity risk (crude oil and natural gas)
 
is related to future market prices as Equinor´s risk
policy is to be exposed to both upside and downside price movements. In the longer term, also
 
power price risk is to a large extent
expected to contribute to Equinor’s commodity price risk portfolio.
To manage short-term commodity risk, Equinor enters into
commodity-based derivative contracts, including futures,
 
options, over-the-counter (OTC) forward contracts, market swaps and
contracts for differences related to crude oil, petroleum products, natural gas, power and emissions. Equinor’s
 
bilateral gas sales
portfolio is exposed to various price indices with a combination of gas price markers.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
166
 
Equinor, Annual Report on Form 20-F 2022
 
The term of crude oil and refined oil products derivatives are usually less than one year, and they are traded mainly on the Inter-
Continental Exchange (ICE) in London, the New York Mercantile Exchange (NYMEX), the OTC Brent market, and crude and refined
products swap markets. The term of natural gas, power, and emission derivatives is usually three years or less, and they are mainly
OTC physical forwards and options, NASDAQ OMX Oslo forwards, and futures traded on the European
 
Energy Exchange (EEX),
NYMEX and ICE.
The table below contains the commodity price risk sensitivities of Equinor's commodity-based derivative
 
contracts. Equinor's assets
and liabilities resulting from commodity-based derivative contracts consist of both exchange traded and non-exchange
 
traded
instruments, including embedded derivatives that have been bifurcated and recognised at fair value
 
in the Consolidated balance
sheet.
Price risk sensitivities at the end of 2022 and 2021 at 30% are assumed to represent a reasonably possible change based
 
on the
duration of the derivatives. Since none of the derivative financial instruments included in the
 
table below are part of hedging
relationships, any changes in the fair value would be recognised in the Consolidated
 
statement of income.
Commodity price sensitivity
At 31 December
2022
2021
(in USD million)
- 30%
+ 30%
- 30%
+ 30%
Crude oil and refined products net gains/(losses)
666
(666)
735
(735)
Natural gas, electricity and CO2 net gains/(losses)
(3)
140
227
(141)
Currency risk
Equinor’s cash flows from operating activities deriving from oil and gas sales, operating
 
expenses and capital expenditures are mainly
in USD, but taxes, dividends to shareholders on the Oslo Børs and a share of our operating
 
expenses and capital expenditures are in
NOK. Accordingly, Equinor’s currency management is primarily linked to mitigate currency risk related to payments in NOK. This
means that Equinor regularly purchases NOK, primarily spot, but also on a forward basis
 
using conventional derivative instruments.
The following currency risk sensitivity for financial instruments has been calculated, by assuming
 
a 12% reasonable possible change
in the most relevant foreign currency exchange rates that impact Equinor’s
 
financial accounts, based on balances at 31 December
2022. As of 31 December 2021, a change of 10% in the most relevant foreign currency
 
exchange rates was viewed as a reasonable
possible change. With reference to the table below, an increase in the foreign currency exchange rates means that the disclosed
currency has strengthened in value against all other currencies. The estimated gains and the estimated
 
losses following from a
change in the foreign currency exchange rates would impact the Consolidated statement of income.
Currency risk sensitivity
At 31 December
2022
2021
(in USD million)
- 12 %
+ 12%
- 10 %
+ 10%
USD net gains/(losses)
(1,497)
1,497
(1,789)
1,789
NOK net gains/(losses)
1,583
(1,583)
2,144
(2,144)
Interest rate risk
Bonds are normally issued at fixed rates in a variety of currencies (among others USD, EUR
 
and GBP) and some of these bonds are
converted to floating USD bonds by using interest rate and currency swaps. Equinor manages its
 
interest rates exposure on its bond
portfolio based on risk and reward considerations from an enterprise risk management perspective. This means
 
that the fixed/floating
mix on interest rate exposure may vary from time to time. For more detailed information
 
about Equinor’s long-term debt portfolio see
note 21 Finance debt.
The following interest rate risk sensitivity has been calculated by assuming a change of 1.2
 
percentage points as a reasonable
possible change in interest rates at the end of 2022. In 2021, a change of 0.8 percentage
 
points in interest rates was viewed as a
reasonable possible change. A decrease in interest rates will have an estimated positive impact
 
on net financial items in the
Consolidated statement of income, while an increase in interest rates will have an estimated negative
 
impact on net financial items in
the Consolidated statement of income.
Interest risk sensitivity
At 31 December
2022
2021
(in USD million)
 
- 1.2 percentage
points
+ 1.2 percentage
points
 
- 0.8 percentage
points
+ 0.8 percentage
points
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
167
Positive/(negative) impact on net financial items
369
(366)
448
(448)
Equity price risk
Equinor’s captive insurance company holds listed equity securities as part of its portfolio.
 
In addition, Equinor holds some other listed
and non-listed equities mainly for long-term strategic purposes. By holding these assets, Equinor
 
is exposed to equity price risk,
defined as the risk of declining equity prices, which can result in a decline in the carrying
 
value of certain Equinor’s assets recognised
in the balance sheet. The equity price risk in the portfolio held by Equinor’s captive insurance
 
company is managed, with the aim of
maintaining a moderate risk profile, through geographical diversification and the use of broad
 
benchmark indexes.
The following equity price risk sensitivity has been calculated, by assuming a 35% reasonable possible change
 
in equity prices that
impact Equinor’s financial accounts, based on balances at 31 December 2022. At 31 December
 
2021, a change of 35% in equity
prices was equally viewed as a reasonable possible change. The estimated gains and the
 
estimated losses following from a change in
equity prices would impact the Consolidated statement of income.
Equity price sensitivity
At 31 December
2022
2021
(in USD million)
- 35%
+ 35%
- 35%
+ 35%
Net gains/(losses)
(450)
450
(534)
534
Liquidity risk
Liquidity risk is the risk that Equinor will not be able to meet obligations of financial
 
liabilities when they become due. The purpose of
liquidity management is to ensure that Equinor always has sufficient funds available to cover its financial obligations.
The main cash outflows include the quarterly dividend payments and Norwegian petroleum tax payments made
 
six times per year.
Trading in collateralised commodities and financial contracts also exposes Equinor to liquidity risk related to potential collateral calls
from counterparties.
 
If the cash flow forecasts indicate that the liquid assets will fall below target levels,
 
new long-term funding will be considered. Equinor
raises debt in all major capital markets (USA, Europe and Asia) for long-term funding purposes.
 
The policy is to have a maturity profile
with repayments not exceeding 5% of capital employed in any year for the nearest five years. Equinor’s
 
non-current financial liabilities
have a weighted average maturity of approximately nine years. For more information about Equinor’s
 
non-current financial liabilities,
see note 21 Finance debt.
Short-term funding needs will normally be covered by the USD 5.0 billion US Commercial paper programme
 
(CP) which is backed by
a revolving credit facility of USD 6.0 billion, supported by 19 core banks, maturing in 2025.
 
The facility supports secure access to
funding, supported by the best available short-term rating. As at 31 December 2022 the facility
 
has not been drawn upon.
The table below shows a maturity profile, based on undiscounted contractual cash flows, for Equinor’s
 
financial liabilities.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
168
 
Equinor, Annual Report on Form 20-F 2022
 
At 31 December
2022
2021
(in USD million)
Non-derivative financial
liabilities
Lease
liabilities
Derivative
financial
liabilities
Non-derivative financial
liabilities
Lease
liabilities
Derivative
financial
liabilities
Year 1
20,172
1,325
1,065
18,841
1,183
175
Year 2 and 3
6,292
1,421
752
6,684
1,262
211
Year 4 and 5
 
5,785
504
486
6,140
656
318
Year 6 to 10
8,749
465
1,202
10,636
642
588
After 10 years
11,204
120
706
12,849
158
187
Total specified
52,202
3,835
4,211
55,150
3,901
1,479
Credit risk
Credit risk is the risk that Equinor’s customers or counterparties will cause Equinor
 
financial loss by failing to honour their obligations.
Credit risk arises from credit exposures with customer accounts receivables as well as from financial investments,
 
derivative financial
instruments and deposits with financial institutions. Equinor uses risk mitigation tools to reduce
 
or control credit risk both on a
counterparty and portfolio level. The main tools include bank and parental guarantees, prepayments,
 
and cash collateral.
Prior to entering into transactions with new counterparties, Equinor’s credit policy requires all
 
counterparties to be formally identified
and assigned internal credit ratings. The internal credit ratings reflect Equinor’s
 
assessment of the counterparties' credit risk and are
based on a quantitative and qualitative analysis of recent financial statements and other relevant
 
business information. All
counterparties are re-assessed regularly.
Equinor has pre-defined limits for the absolute credit risk level allowed at any given time on Equinor’s
 
portfolio as well as maximum
credit exposures for individual counterparties. Equinor monitors the portfolio on a regular basis
 
and individual exposures against limits
on a daily basis. Equinor’s total credit exposure is geographically diversified among
 
a number of counterparties within the oil and
energy sector, as well as larger oil and gas consumers and financial counterparties. The majority of Equinor’s credit
 
exposure is with
investment- grade counterparties.
The following table contains the carrying amount of Equinor’s financial receivables and
 
derivative financial instruments split by
Equinor’s assessment of the counterparty's credit risk. Trade and other receivables include 1% overdue receivables of more than
 
30
days. A provision has been recognised for expected credit losses of trade and other receivables
 
using the expected credit loss model.
Only non-exchange traded instruments are included in derivative financial instruments.
(in USD million)
Non-current
financial
receivables
Trade and other
receivables
Non-current
derivative
financial
instruments
Current derivative
financial
instruments
At 31 December 2022
Investment grade, rated A or above
1,633
6,125
390
1,715
Other investment grade
12
8,725
41
1,393
Non-investment grade or not rated
14
6,761
259
931
Total financial assets
1,659
21,611
690
4,039
At 31 December 2021
Investment grade, rated A or above
452
3,637
1,103
2,902
Other investment grade
18
8,930
0
1,524
Non-investment grade or not rated
238
4,624
162
705
Total financial assets
708
17,191
1,265
5,131
For more information about Trade and other receivables, see note 18 Trade and other receivables.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
169
The table below presents the amounts offset under the terms of various master netting agreements for financial assets and liabilities.
Amounts not qualifying for offsetting consists of collateral receipts or payments which usually is settled on a gross
 
basis. Normally
these amounts will offset in a potential default situation. There exist no restrictions on collaterals received.
(in USD million)
Gross amounts of
recognised
financial assets/
liabilities
Gross amounts
offset in the
balance sheet
Net amounts
presented in the
balance sheet
Amounts of
remaining rights
to set-off not
qualifying for
offsetting
Net amount
At 31 December 2022
Financial assets
Trade receivables
25,607
7,464
18,143
0
18,143
Collateral receivables
19,043
15,575
3,468
3,468
0
Derivative financial instruments
30,078
25,348
4,730
1,708
3,022
Total financial assets
74,728
48,387
26,341
5,176
21,165
Financial liabilities
Trade payables
19,913
7,464
12,449
0
12,449
Collateral liabilities
15,479
13,907
1,572
1,571
1
Derivative financial instruments
33,497
27,015
6,482
3,605
2,877
Total financial liabilities
68,889
48,386
20,503
5,176
15,327
(in USD million)
Gross amounts of
recognised
financial assets/
liabilities
1)
Gross amounts
offset in the
balance sheet
1)
Net amounts
presented in the
balance sheet
Amounts of
remaining rights
to set-off not
qualifying for
offsetting
Net amount
At 31 December 2021
Financial assets
Trade receivables
20,061
4,445
15,616
0
15,616
Collateral receivables
1)
9,902
8,327
1,576
1,576
0
Derivative financial instruments
1)
32,493
26,097
6,396
2,771
3,625
0
Total financial assets
1)
62,456
38,869
23,588
4,347
19,241
0
Financial liabilities
0
Trade payables
16,795
4,445
12,350
0
12,350
Collateral liabilities
1)
9,851
7,580
2,271
2,271
0
Derivative financial instruments
1)
32,218
26,844
5,375
2,076
3,299
Total financial liabilities
1)
58,864
38,869
19,996
4,347
15,649
1) Gross amounts have been restated due to reassessment of certain exchange traded derivatives and related
 
collaterals previously
not recognised on the Consolidated balance sheet, with no effect on net amounts presented.
Capital management
 
 
 
 
 
 
 
 
 
 
170
 
Equinor, Annual Report on Form 20-F 2022
 
The main objectives of Equinor's capital management policy are to maintain a strong overall financial
 
position and to ensure sufficient
financial flexibility. Equinor’s primary focus is on maintaining its credit rating in the A category on a stand alone basis (excluding uplifts
for Norwegian Government ownership). Equinor’s current long-term ratings are AA- with
 
a stable outlook (including one notch uplift)
and Aa2 with a stable outlook (including two notch uplift) from S&P
 
and Moody’s, respectively. In order to monitor financial robustness,
a key ratio utilised by Equinor is the non-GAAP metric of “Net interest-bearing debt adjusted (ND)
 
to Capital employed adjusted*
(CE)”.
At 31 December
(in USD million)
2022
2021
Net interest-bearing debt adjusted, including lease
 
liabilities (ND1)
(6,750)
3,236
Net interest-bearing debt adjusted (ND2)
(10,417)
(326)
Capital employed adjusted, including lease liabilities
 
(CE1)
47,239
42,259
Capital employed adjusted (CE2)
43,571
38,697
Net debt to capital employed adjusted*, including lease
 
liabilities (ND1/CE1)
(14.3%)
7.7%
Net debt to capital employed adjusted* (ND2/CE2)
(23.9%)
(0.8%)
ND1 is defined as Equinor's interest-bearing financial liabilities less cash and cash equivalents and current
 
financial investments,
adjusted for collateral deposits and balances held by Equinor's captive insurance company (amounting to USD 6,538 million
 
and USD
2,369 million for 2022 and 2021, respectively). CE1 is defined as Equinor's total equity (including non-controlling
 
interests) and ND1.
ND2 is defined as ND1 adjusted for lease liabilities (amounting to USD 3,668 million
 
and USD 3,562 million for 2022 and 2021,
respectively). CE2 is defined as Equinor's total equity (including non-controlling interests) and ND2.
5 Segments
Accounting policies
Equinor’s operations are managed through operating segments identified on the
 
basis of those components of Equinor that are
regularly reviewed by the chief operating decision maker, Equinor's corporate executive committee (CEC). The reportable segments
Exploration & Production Norway (E&P Norway), Exploration & Production International (E&P
 
International), Exploration & Production
USA (E&P USA), Marketing, Midstream & Processing (MMP) and Renewables
 
(REN) correspond to the operating segments. The
operating segments Projects, Drilling & Procurement (PDP), Technology, Digital & Innovation (TDI) and Corporate staff and functions
are aggregated into the reportable segment Other based on materiality. The majority of the costs in PDP and TDI is allocated to the
three Exploration & Production segments, MMP and REN.
The accounting policies of the reporting segments equal those described in these Consolidated
 
financial statements, except for the
line-item Additions to PP&E, intangibles and equity accounted investments in which movements
 
related to changes in asset retirement
obligations are excluded as well as provisions for onerous contracts which reflect only obligations
 
towards group external parties. The
measurement basis of segment profit is net operating income/(loss). Deferred tax assets, pension
 
assets, non-current financial assets,
total current assets and total liabilities are not allocated to the segments. Transactions between the segments, mainly
 
from the sale of
crude oil, gas,
 
and related products, are performed at defined internal prices which have been derived from market
 
prices. The
transactions are eliminated upon consolidation.
With effect from 2022, Equinor changed the measurement basis for the segments related to leases. Up to and
 
including 2021, all
leases were presented within the Other segment and lease costs were allocated to the
 
operating segments based on underlying lease
payments with a corresponding credit in the Other segment. With effect from 2022, lease contracts are
 
accounted for in accordance
with IFRS 16 Leases in all segments. This change does not affect Equinor’s Consolidated financial
 
statements except the segment
disclosures in this note. Comparative numbers in the segments have been restated.
----------------------------------------------------------------------------------------------------------------------------------------
The Exploration & Production operating segments are responsible for the discovery and appraisal
 
of new resources, commercial
development and safe and efficient operation of the oil and gas portfolios within their respective geographical
 
areas: E&P Norway on
the Norwegian continental shelf, E&P USA in USA and E&P International worldwide outside of
 
E&P Norway and E&P USA.
PDP is responsible for global project development, well deliveries, and sourcing across Equinor.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
171
TDI encompasses research, technology development, specialist advisory services, digitalisation, IT, improvement, innovation, and
ventures and future business.
MMP is responsible for the marketing, trading, processing and transportation of crude oil and condensate,
 
natural gas, NGL and
refined products, and includes refinery, terminals, and processing plant operation. MMP is also managing power and emissions trading
and the development of transportation solutions for natural gas, liquids, and crude oil, including pipelines,
 
shipping, trucking and rail. In
addition, MMP is in charge of low carbon solutions in Equinor.
REN is developing, exploring, investing in, and operating areas within renewable energy such as
 
offshore wind, green hydrogen,
storage solutions, and solar power.
Segment information for the years ended 31 December 2022, 2021, and 2020 are presented below. For revenues per geographical
area, please see note 7 Total revenues and other income. For further information on the following items affecting the segments,
please refer to the related notes: note 6 Acquisitions and disposals, note 14 Impairments, and note 26 Other
 
commitments, contingent
liabilities, and contingent assets.
 
2022
E&P
Norway
 
E&P
International
E&P USA
MMP
REN
Other
Eliminations
 
Total
 
(in USD million)
Revenues third party, other revenue and
other income
1,299
1,134
305
147,173
127
149
0
150,186
Revenues inter-segment
74,631
6,124
5,217
527
0
55
(86,554)
0
Net income/(loss) from equity accounted
investments
0
172
0
406
58
(16)
0
620
Total revenues and other income
 
75,930
7,431
5,523
148,105
185
187
(86,554)
150,806
Purchases [net of inventory variation]
0
(116)
0
(139,916)
0
0
86,227
(53,806)
Operating, selling, general and
administrative expenses
(3,782)
(1,698)
(938)
(4,591)
(265)
(223)
904
(10,595)
Depreciation and amortisation
(4,986)
(1,445)
(1,422)
(881)
(4)
(142)
0
(8,878)
Net impairment (losses)/reversals
819
(286)
1,060
895
0
0
0
2,487
Exploration expenses
(366)
(638)
(201)
0
0
0
0
(1,205)
Total operating expenses
(8,315)
(4,183)
(1,501)
(144,493)
(269)
(365)
87,131
(71,995)
Net operating income/(loss)
67,614
3,248
4,022
3,612
(84)
(178)
577
78,811
Additions to PP&E, intangibles and equity
accounted investments
4,922
2,623
764
1,212
298
176
0
9,994
Balance sheet information
Equity accounted investments
 
3
550
0
688
1,452
65
0
2,758
Non-current segment assets
 
28,510
15,868
11,311
4,619
316
1,031
0
61,656
Non-current assets not allocated to
segments
 
15,437
Total non-current assets
 
79,851
Assets classified as held for sale
0
1,018
0
0
0
0
0
1,018
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
172
 
Equinor, Annual Report on Form 20-F 2022
 
 
2021
E&P
Norway
1)
E&P
International
1)
E&P
 
USA
1)
MMP
1)
REN
1)
Other
1)
Eliminations
1
)
Total
(in USD million)
Revenues third party, other revenue and
other income
1)
414
1,121
377
87,050
1,394
307
0
90,665
Revenues inter-segment
1)
38,972
4,230
3,771
321
0
41
(47,335)
0
Net income/(loss) from equity accounted
investments
0
214
0
22
16
7
0
259
Total revenues and other income
1)
39,386
5,566
4,149
87,393
1,411
355
(47,335)
90,924
Purchases [net of inventory variation]
0
(58)
0
(80,873)
0
(1)
45,772
(35,160)
Operating, selling, general and
administrative expenses
1)
(3,653)
(1,405)
(1,074)
(3,753)
(163)
(432)
1,102
(9,378)
Depreciation and amortisation
1)
(6,002)
(1,734)
(1,665)
(869)
(3)
(158)
0
(10,432)
Net impairment (losses)/reversals
1)
1,102
(1,587)
(69)
(735)
0
2
0
(1,287)
Exploration expenses
(363)
(451)
(190)
0
0
0
0
(1,004)
Total operating expenses
1)
(8,915)
(5,237)
(2,998)
(86,230)
(166)
(590)
46,873
(57,261)
Net operating income/(loss)
1)
30,471
329
1,150
1,163
1,245
(234)
(461)
33,663
Additions to PP&E, intangibles and equity
accounted investments
1)
4,943
1,834
690
517
457
64
0
8,506
Balance sheet information
Equity accounted investments
 
3
1,417
0
113
1,108
45
0
2,686
Non-current segment assets
1)
36,502
15,422
11,406
4,006
157
1,032
0
68,527
Non-current assets not allocated to
segments
 
13,406
Total non-current assets
 
84,618
Assets classified as held for sale
0
676
0
0
0
0
0
676
1)
Restated due to implementation of IFRS 16 in the
 
segments, mainly affecting the line items Operating, selling,
 
general and administrative
expenses in MMP (reduction of USD 523 million),
 
E&P Norway (reduction of USD 77 million)
 
and Other (increase of USD 696 million),
Depreciation and amortisation in MMP (increase of
 
USD 509 million), E&P Norway (increase
 
of USD 222 million) and Other (reduction of
USD 799 million) and Non-current segment assets
 
in MMP (increase of USD 987 million), E&P Norway
 
(increase of USD 1,201 million)
and Other (decrease of USD 2,255 million).
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
173
2020
E&P
Norway
1)
E&P
International
1)
E&P
 
USA
MMP
1)
REN
1)
Other
1)
Eliminations
Total
(in USD million)
Revenues third party, other revenue and
other income
1)
215
452
368
44,623
18
88
0
45,765
Revenues inter-segment
11,804
3,183
2,247
309
0
39
(17,581)
0
Net income/(loss) from equity accounted
investments
0
(146)
0
31
163
5
0
53
Total revenues and other income
1)
12,019
3,489
2,615
44,963
181
132
(17,581)
45,818
Purchases [net of inventory variation]
0
(72)
0
(38,072)
0
1
17,157
(20,986)
Operating, selling, general and
administrative expenses
1)
(2,736)
(1,374)
(1,310)
(4,564)
(214)
(59)
722
(9,537)
Depreciation and amortisation
1)
(4,466)
(2,105)
(1,889)
(875)
(1)
(178)
(1)
(9,515)
Net impairment (losses)/reversals
1)
(1,260)
(1,426)
(1,938)
(1,076)
0
(19)
(1)
(5,720)
Exploration expenses
(423)
(2,071)
(990)
0
0
1
(1)
(3,483)
Total operating expenses
1)
(8,886)
(7,048)
(6,127)
(44,587)
(216)
(254)
17,877
(49,241)
Net operating income/(loss)
1)
3,133
(3,559)
(3,512)
376
(35)
(122)
295
(3,423)
Additions to PP&E, intangibles and equity
accounted investments
1)
5,004
2,588
1,067
1,048
33
22
0
9,762
Balance sheet information
Equity accounted investments
3
1,125
0
95
1,017
25
0
2,262
Non-current segment assets
1)
39,355
17,960
12,588
5,605
4
1,144
0
76,657
Non-current assets not allocated to
segments
13,704
Total non-current assets
92,623
Assets classified as held for sale
0
0
1,159
0
203
0
0
1,362
1)
Restated due to implementation of IFRS 16 in the
 
segments, mainly affecting the line items Operating, selling,
 
general and administrative
expenses in MMP (reduction of USD 494 million),
 
E&P Norway (reduction of USD 93 million)
 
and Other (increase of USD 693 million),
Depreciation and amortisation in MMP (increase of
 
USD 481 million), E&P Norway (increase
 
of USD 181 million) and Other (reduction of
USD 718 million) and Non-current segment assets
 
in MMP (increase of USD 1,238 million), E&P Norway
 
(increase of USD 1,623 million)
and Other (decrease of USD 2,987 million).
 
 
 
 
 
 
 
 
 
 
174
 
Equinor, Annual Report on Form 20-F 2022
 
Non-current assets by country
At 31 December
(in USD million)
2022
2021
Norway
33,242
40,564
USA
12,343
12,323
Brazil
9,400
8,751
UK
3,688
2,096
Azerbaijan
1,401
1,654
Canada
1,171
1,403
Angola
895
948
Algeria
622
708
Argentina
615
474
Denmark
497
536
Other
541
1,757
Total non-current assets
1)
64,414
71,213
1)
Excluding deferred tax assets, pension assets and
 
non-current financial assets.
 
Equinor’s non-current assets in Norway have decreased by USD 7,322 million to USD
 
33,242 million at 31 December 2022 compared
to year-end 2021, mainly due to increased discount rates and strengthening of USD versus NOK.
 
The decrease has mainly affected
Property, plant and equipment,
 
see note 12.
 
 
Equinor, Annual Report on Form 20-F 2022
 
175
6 Acquisitions and disposals
Accounting policies
Business combinations
Business combinations, except for transactions between entities under common control, are accounted for
 
using the acquisition
method. The purchase price includes total consideration paid to acquire the entity’s assets and liabilities, as well
 
as contingent
consideration at fair value. The acquired identifiable assets, liabilities and contingent liabilities are
 
measured at fair value at the date of
the acquisition. Acquisition costs incurred are expensed under Selling, general and administrative
 
expenses. Changes in the fair value
of contingent consideration resulting from events after the acquisition date are recognised in
 
the Consolidated statement of income
under Other income.
Equinor recognises a gain/loss on disposal of a subsidiary when control is lost. Any remaining
 
interest in the former subsidiary is
recognised at fair value. When partially divesting subsidiaries which do not constitute a business, and where
 
the remaining investment
in the former subsidiary is an associate or a jointly controlled investment, Equinor only recognises
 
the gain or loss on the divested part
within Other income or Operating expenses, respectively. The remaining interest in the former subsidiary is initially not remeasured,
and subsequently accounted for using the equity method.
After-tax disposals
On the NCS, all disposals of assets are performed including the tax base (after-tax). Any gain
 
includes the release of tax liabilities
previously recognised related to the assets in question and is recognised in full in Other income in
 
the Consolidated statement of
income.
Assets classified as held for sale
Non-current assets are classified separately as held for sale in the Consolidated balance sheet when
 
a sale is highly probable. This
condition is met when an asset is available for immediate sale in its present condition,
 
Equinor’s management is committed to the
sale, and the sale is expected to be completed within one year from the date
 
of classification. In Equinor, these requirements are
normally met when management has approved a negotiated letter of intent with the
 
counterparties (a ‘DGC’). Liabilities directly
associated with the assets classified as held for sale and expected to be included as part of the
 
sales transaction, are also classified
separately. The net assets and liabilities of a disposal group classified as held for sale are measured at the lower of their carrying
amount and fair value less costs to sell.
Accounting judgement regarding acquisitions
Determining whether an acquisition meets the definition of a business combination requires judgement to
 
be applied on a case-by-
case basis. Acquisitions are assessed to establish whether the transaction represents a business
 
combination or an asset purchase,
and the conclusion may materially affect the financial statements both in the transaction period and subsequent
 
periods. Similar
assessments are performed upon the acquisition of an interest in a joint operation. Depending
 
on the specific facts, acquisitions of
exploration and evaluation licences for which a development decision has not yet been made have
 
largely been concluded to
represent asset purchases, while purchases of producing assets have largely been concluded to
 
represent business acquisitions.
Accounting judgement regarding partial divestments
The policy regarding partial divestments of subsidiaries is based on careful consideration of the
 
requirements and scope of IFRS 10
Consolidated Financial Statements and IAS 28 Investments in Associates and Joint Ventures. The conclusion requires judgement to
be applied on a case-by-case basis, considering the substance of the transactions. In evaluating
 
the standards’ requirements, Equinor
acknowledges pending considerations related to several relevant and similar issues which have
 
been postponed by the IASB in
anticipation of concurrent consideration at a later date. Where assets are transferred into separate legal
 
entities concurrently with a
portion of the entities’ shares being sold to a third party, thereby resulting in Equinor’s loss of control of those asset-owning
subsidiaries, and where investments in joint ventures are established simultaneously, Equinor has concluded to only recognise the
gain on the divested portion.
----------------------------------------------------------------------------------------------------------------------------------------
2022
Acquisitions
Acquisition of BeGreen
On 26 January 2023, Equinor closed a transaction with the Bregentved Group
 
and members of the executive board of BeGreen Solar
Aps to acquire 100% of BeGreen Solar Aps for a cash consideration of USD 277
 
million (EUR 260 million) and a consideration
contingent on successful delivery of future solar projects above an agreed MW threshold. BeGreen
 
Solar Aps is a Danish solar
developer. At closing, USD 226 million (EUR 213 million) of the cash consideration was paid and recognised in the REN
 
segment.
Acquisition of Triton Power
176
 
Equinor, Annual Report on Form 20-F 2022
 
On 1 September 2022, Equinor and SSE Thermal Generation Holdings Limited (SSE
 
Thermal) closed a transaction to acquire the UK
power company Triton Power Holdings Ltd (Triton Power) from Triton Power Partners LP owned by Energy Capital Partners (ECP).
Equinor’s share of the consideration was USD 141 million (GBP 120 million), after
 
adjustments that mainly related to net debt and
working capital. The key plant included in the purchase of Triton Power is the Saltend Power Station with an installed
 
capacity of 1.2
GW. Equinor and SSE Thermal own 50% each of Triton Power, and Equinor is accounting for the investment under the equity method
as a joint venture in the MMP segment.
Acquisition of Statfjord licence shares
On 31 May 2022, Equinor closed a transaction to acquire all of Spirit Energy’s interests in
 
production licences in the Statfjord area
which covers the Norwegian and UK Continental Shelves and consists of three integrated
 
production platforms and satellite subsea
installations. All licences are operated by Equinor. Spirit Energy’s ownership shares in the licences covered by the transaction range
from 11.56% to 48.78%. The cash consideration received was USD 193 million, whereof USD 25 million related to Spirit’s lifting of
volumes on Equinor’s behalf in June 2022. The assets and liabilities acquired have
 
been reflected in accordance with the principles in
IFRS 3 Business Combinations. The transaction is reflected in the E&P Norway and E&P
 
International segments with a cash
consideration of USD 96 million and USD 72 million,
 
respectively.
In the segment E&P Norway, the acquisition resulted in an increase of USD 98 million in property, plant and equipment, an increase of
USD 390 million in asset retirement obligation, a reduction of deferred tax liability of USD 298
 
million and an increase in taxes payable
of USD 98 million. In the segment E&P International, the acquisition resulted in an increase
 
of USD 98 million in property, plant and
equipment, an increase of USD 241 million in asset retirement obligation and an increase of deferred
 
tax asset of USD 86 million.
Disposals
Ekofisk and Martin Linge on the Norwegian Continental Shelf
On 30 September 2022, Equinor closed a transaction with Sval Energi AS to divest Equinor’s
 
entire ownership share in the Greater
Ekofisk Area including its share in Norpipe Oil AS, and a 19% ownership share in Martin Linge.
 
The cash consideration paid upon
closing of the transaction amounted to USD 293 million after interim period settlement.
 
In addition, an estimated contingent
consideration of USD 169 million linked to realised oil and gas prices for 2022 and 2023 was
 
recognised. Equinor retained a 51%
ownership share in Martin Linge and continues as operator of the field. The disposal
 
resulted in a decrease in property, plant and
equipment of USD 1,493 million, a decrease in asset retirement obligation of USD 376 million,
 
a decrease in deferred tax liability of
USD 597 million and a decrease in taxes payable of USD 686 million. A post-tax gain
 
of USD 655 million is presented in the line item
Other income in the Consolidated statement of income in the E&P Norway segment.
Exit Russia
Following Russia’s invasion of Ukraine in February 2022, Equinor announced that it had decided to stop new investments
 
in Russia
and start the process of exiting Equinor’s joint arrangements. Based on this
 
decision, Equinor evaluated its assets in Russia and
recognised net impairments of USD 1,083 million in the first quarter, of which USD 251 million was related to property, plant and
equipment and intangible assets and USD 832 million was related to investments accounted
 
for using the equity method. The
impairments were net of contingent consideration from the time of acquiring the assets. The impairments
 
were recognised in the line
items Depreciation, amortisation and net impairment losses and Exploration expenses in the Consolidated
 
statement of income based
on the nature of the impaired assets and reflected in the E&P International segment. During
 
the second quarter, Equinor transferred
its participating interests in four Russian entities to Rosneft and was released from all future
 
commitments and obligations with no
material impact on the financial statements. The ownership interests in Kharyaga were transferred
 
to the operator.
Equinor has stopped trading in Russian oil. This means that Equinor will not enter into any new
 
trades or engage in new transport of
oil and oil products from Russia. Equinor has assessed the accounting impact of certain commitments
 
arising from such contracts
entered into prior to the invasion and deem the impact to be immaterial.
10% of Dogger Bank C
On 10 February 2022, Equinor closed the transaction with Eni to sell a 10% equity interest in the
 
Dogger Bank C project in the UK for
a total consideration of USD 91 million (GBP 68 million), resulting in a gain of USD
 
87 million (GBP 65 million). After closing, Equinor’s
ownership share is 40%. Equinor continues to equity account for the remaining investment as a
 
joint venture. The gain is presented in
the line item Other income in the Consolidated statement of income in the REN segment.
Held for sale
Equinor Energy Ireland Limited
In the fourth quarter of 2021, Equinor entered into an agreement with Vermilion Energy Inc (Vermilion) to sell Equinor’s non-operated
equity position in the Corrib gas project in Ireland. The transaction covers a sale of
 
100% of the shares in Equinor Energy Ireland
Limited (EEIL). EEIL owns 36.5% of the Corrib field alongside the operator Vermilion (20%) and Nephin Energy (43.5%).
 
Equinor and
Equinor, Annual Report on Form 20-F 2022
 
177
Vermilion have agreed a consideration of USD 434 million before closing adjustments and contingent consideration linked to 2022
production level and gas prices. Closing is dependent on governmental approval and is expected
 
to take place during the first quarter
2023.
2021
Acquisitions
Wento
On 5 May 2021, Equinor completed a transaction to acquire 100% of the shares in Polish
 
onshore renewables developer Wento from
the private equity firm Enterprise Investors for a cash consideration of USD 117 million (EUR 98 million) after net cash adjustments.
The assets and liabilities related to the acquired business were recognised under the acquisition method. The
 
acquisition resulted in
an increase of Equinor’s intangible assets of USD 46 million and goodwill
 
of USD 59 million. The goodwill reflects the expected
synergies, competence and access to the Polish renewables market obtained in the acquisition.
 
The transaction has been accounted
for in the REN segment.
Disposals
Equinor Refining Denmark A/S
On 31 December 2021, Equinor Danmark A/S closed the transaction with the Klesch Group to sell 100%
 
of the shares in Equinor
Refining Denmark A/S (ERD). Klesch paid USD 48 million of the total estimated consideration
 
at closing. ERD consists of
the Kalundborg refinery and associated terminals and infrastructure. Following an impairment earlier
 
in 2021, the disposal resulted in
an immaterial loss. Prior to transaction closing, Equinor received USD 335 million in extraordinary
 
dividend and repayment of paid-
in capital from ERD.
 
Following the disposal, a gain of USD 167 million was recycled from Other comprehensive income (OCI)
 
to the Consolidated
statement of income in the line item Other income and has been reflected in the MMP segment.
Terra Nova
On 8 September 2021, Equinor closed the transaction with Cenovus and Murphy to
 
sell 100% of its interest, which includes a release
of any future obligations and liabilities, in the Terra Nova asset in offshore Canada. The transaction was accounted for in the E&P
International segment. The consideration paid, the net carrying amount and the impact to the Consolidated
 
statement of income are
immaterial.
Bakken onshore unconventional field
On 26 April 2021, Equinor closed the transaction to divest its interests in the Bakken
 
field in the US states of North Dakota and
Montana to Grayson Mill Energy, backed by EnCap Investments for an estimated total consideration of USD 819 million, including
interim period settlement, for which payment was received in the first half of 2021. The asset had
 
been impaired in 2021 prior to
closing. Subsequent to closing, insignificant losses were recorded and are presented in the line item Operating
 
expenses in the
Consolidated statement of income in the E&P USA segment.
10% of Dogger Bank Farm A and B
On 26 February 2021, Equinor closed the transaction with Eni to sell a 10% equity interest in
 
the Dogger Bank Wind Farm A and B
assets in the UK for a total consideration of USD 285 million (GBP 206 million), resulting
 
in a gain of USD 280 million (GBP 203
million). After closing, Equinor has a 40% shareholding in Dogger Bank A and Dogger Bank B,
 
and will continue to equity account for
the remaining investment as a joint venture. The gain is presented in the line item Other
 
income in the Consolidated statement of
income in the REN segment.
Non-operated interest in the Empire Wind and Beacon Wind assets on the US east coast
On 29 January 2021, Equinor closed the transaction with BP to sell 50% of the
 
non-operated interests in the Empire Wind and Beacon
Wind assets for a preliminary total consideration after interim period adjustments of USD 1.2 billion, resulting
 
in a gain of USD 1.1
billion for the divested part, of which USD 500 million had been prepaid at the end
 
of December 2020. Through this transaction, the
two companies have established a strategic partnership for further growth within offshore wind in the USA.
 
Following the transaction,
Equinor remains the operator with a 50% interest. Equinor consolidated the assets until transaction
 
closing, and thereafter the
investments are classified as joint ventures and accounted for using the equity method. The gain is
 
presented in the line item Other
income in the Consolidated statement of income in the REN segment.
7 Total
 
revenues and other income
Accounting policies
Revenue recognition
Equinor presents Revenue from contracts with customers and Other revenue as a single caption,
 
Revenues, in the Consolidated
statement of income.
 
 
 
 
 
 
 
 
 
 
 
178
 
Equinor, Annual Report on Form 20-F 2022
 
Revenue from contracts with customers
Revenue from the sale of crude oil, natural gas, petroleum products and other merchandise is
 
recognised when a customer obtains
control of those products, which normally is when title passes at point of delivery, based on the contractual terms of the agreements.
Each such sale normally represents a single performance obligation. In the case of natural gas,
 
which is delivered on a continuous
basis through pipelines, sales are completed over time in line with the delivery of the actual physical quantities.
Sales and purchases of physical commodities are presented on a gross basis as Revenues from contracts
 
with customers and
Purchases [net of inventory variation] respectively in the Consolidated statement of income. When the
 
contracts are deemed financial
instruments or part of Equinor’s trading activities, they are settled and presented
 
on a net basis as Other revenue. Reference is made
to note 28 Financial instruments and fair value measurement for a description of accounting policies
 
regarding derivatives. Sales of
Equinor’s own produced oil and gas volumes are always reflected gross as Revenue
 
from contracts with customers.
Revenues from the production of oil and gas in which Equinor shares an interest with
 
other companies are recognised on the basis of
volumes lifted and sold to customers during the period (the sales method). Where Equinor
 
has lifted and sold more than the
ownership interest, an accrual is recognised for the cost of the overlift. Where Equinor has lifted
 
and sold less than the ownership
interest, costs are deferred for the underlift.
Other revenue
Items representing a form of revenue, or which are related to revenue from contracts with customers,
 
are presented as Other revenue
if they do not qualify as revenue from contracts with customers. These other revenue
 
items include taxes paid in-kind under certain
production sharing agreements (PSAs) and the net impact of commodity trading and commodity-based derivative
 
instruments related
to sales contracts or revenue-related risk management.
Transactions with the Norwegian State
Equinor markets and sells the Norwegian State's share of oil and gas production from the
 
Norwegian continental shelf (NCS). The
Norwegian State's participation in petroleum activities is organised through the SDFI (the Norwegian State’s Direct
 
Financial
Interests). All purchases and sales of the SDFI's oil production are classified as purchases [net of
 
inventory variation] and revenues
from contracts with customers, respectively.
Equinor sells, in its own name, but for the SDFI’s account and risk, the SDFI’s production of natural gas. These gas sales
 
and related
expenditures refunded by the SDFI are presented net in the Consolidated financial statements. Natural gas
 
sales made in the name of
Equinor’s subsidiaries are also presented net of the SDFI’s share in the Consolidated statement of income,
 
but this activity is reflected
gross in the Consolidated balance sheet.
Accounting judgement related to transactions with the Norwegian State
Whether to account for the transactions gross or net involves the use of significant
 
accounting judgement. In making the judgement,
Equinor has considered whether it controls the State-originated crude oil volumes prior to onwards
 
sales to third party customers.
Equinor directs the use of the volumes, and although certain benefits from the sales subsequently
 
flow to the SDFI, Equinor
purchases the crude oil volumes from the SDFI and obtains substantially all the remaining benefits. On
 
that basis, Equinor has
concluded that it acts as principal in these sales.
Regarding gas sales, Equinor concluded that ownership of the gas had not been transferred from
 
the SDFI to Equinor. Although
Equinor has been granted the ability to direct the use of the volumes, all the benefits from the
 
sales of these volumes flow to the SDFI.
On that basis, Equinor is not considered the principal in the sale of the SDFI’s natural gas volumes.
Reference is made to note 27 Related parties for detailed financial information regarding transactions
 
performed between Equinor and
SDFI.
----------------------------------------------------------------------------------------------------------------------------------------
Revenues from contracts with customers by geographical areas
Equinor has business operations in around 30
 
countries.
When attributing the line-item Revenues from contracts with customers for 2022
to the country of the legal entity executing the sale for 2022, Norway constitutes 84% and USA constitutes
 
13%. For 2021 the
revenues to Norway and USA constituted 81% and 13% respectively, and for 2020 80% and 14% respectively.
Revenues from contracts with customers and
 
other revenues
(in USD million)
Note
2022
2021
2020
Crude oil
58,524
38,307
24,509
Natural gas
65,232
28,050
7,213
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
179
 
- European gas
58,239
24,900
5,839
 
- North American gas
2,884
1,783
1,010
 
- Other incl LNG
4,109
1,368
363
Refined products
11,093
11,473
6,534
Natural gas liquids
9,240
8,490
5,069
Transportation
1,470
921
1,083
Other sales
4,702
1,006
681
Total revenues from contracts with customers
150,262
88,247
45,088
Taxes paid in-kind
412
345
93
Physically settled commodity derivatives
(2,534)
(1,075)
209
Gain/(loss) on commodity derivatives
739
951
108
Change in fair value of trading inventory
(194)
0
0
Other revenues
319
276
256
Total other revenues
(1,258)
497
665
Revenues
149,004
88,744
45,753
Net income/(loss) from equity accounted investments
15
620
259
53
Other income
6
1,182
1,921
12
Total revenues and other income
150,806
90,924
45,818
 
 
 
 
 
 
 
 
 
180
 
Equinor, Annual Report on Form 20-F 2022
 
8 Salaries and personnel expenses
 
(in USD million, except average number of employees)
2022
2021
2020
Salaries
1)
2,875
2,962
2,625
Pension costs
2)
458
488
432
Payroll tax
433
414
368
Other compensations and social costs
324
288
283
Total payroll expenses
4,090
4,152
3,707
Average number of employees
3)
21,500
21,400
21,700
1)
 
Salaries include bonuses, severance packages and expatriate costs in addition to base pay.
2)
 
See note 22 Pensions.
3)
 
Part time employees amount to 3% for 2022 and 2021 and 2% for 2020.
Total payroll expenses are accumulated in cost-pools and partially charged to partners of Equinor operated licences on an hours
incurred basis.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
181
Compensation to the board of directors (BoD) and the corporate executive committee
 
(CEC)
(in USD million)
1)
2022
2021
2020
Current employee benefits
12.9
12.2
9.0
Post-employment benefits
0.4
0.4
0.6
Other non-current benefits
0.0
0.0
0.0
Share-based payment benefits
0.2
0.1
0.1
Total benefits
13.5
12.7
9.7
1) All figures in the table are presented on accrual basis.
At 31 December 2022, 2021, and 2020 there are no loans to the members of the
 
BoD or the CEC.
Share-based compensation
Equinor's share saving plan provides employees with the opportunity to purchase Equinor shares through
 
monthly salary deductions
and a contribution by Equinor. If the shares are kept for two full calendar years of continued employment following the year of
purchase, the employees will be allocated one bonus share for each share they have purchased.
Estimated compensation expense including the contribution by Equinor for purchased shares, amounts
 
vested for bonus shares
granted and related social security tax was USD 85 million, USD 79 million, and USD
 
74 million related to the 2022, 2021 and 2020
programmes, respectively. For the 2023 programme (granted in 2022), the estimated compensation expense is USD 78 million. At 31
December 2022 the amount of compensation cost yet to be expensed throughout the vesting period is USD
 
174 million.
See note 20 Shareholders’ equity and dividends for more information about share-based
 
compensation.
9 Auditor’s remuneration and Research and development expenditures
 
Auditor's remuneration
Full year
(in USD million, excluding VAT)
2022
2021
2020
Audit fee
11.4
14.4
10.7
Audit related fee
 
1.8
1.1
1.0
Tax fee
-
-
-
Other service fee
 
-
-
-
Total remuneration
13.2
15.5
11.7
In addition to the figures in the table above, the audit fees and audit related fees related to Equinor
 
operated licences amount to USD
0.6 million, USD 0.5 million and USD 0.5 million for 2022, 2021 and 2020, respectively.
Research and development expenditures (R&D)
Equinor has R&D activities within exploration, subsurface, drilling and well, facilities, low carbon
 
and renewables. R&D activities
contribute to maximising and developing long-term value from Equinor’s assets. R&D
 
expenditures are partially financed by partners
of Equinor operated licences.
R&D expenditures including amounts charged to partners were USD 308 million, USD 291 million
 
and USD 254 million in 2022, 2021
and 2020, respectively. Equinor's share of the expenditures has been recognised within Total operating expenses in the Consolidated
statement of income.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
182
 
Equinor, Annual Report on Form 20-F 2022
 
10 Financial items
Full year
(in USD million)
2022
2021
2020
Foreign currency exchange gains/(losses) derivative
 
financial instruments
 
797
870
(1,288)
Other foreign currency exchange gains/(losses)
1,291
(823)
642
Net foreign currency exchange gains/(losses)
2,088
47
(646)
Dividends received
93
39
44
Interest income financial investments, including cash
 
and cash equivalents
398
38
108
Interest income non-current financial receivables
30
26
34
Interest income other current financial assets and other
 
financial items
701
48
113
Interest income and other financial items
1,222
151
298
Gains/(losses) financial investments
(394)
(348)
456
Gains/(losses) other derivative financial instruments
(1,745)
(708)
448
Interest expense bonds and bank loans and net
 
interest on related derivatives
(1,029)
(896)
(951)
Interest expense lease liabilities
(90)
(93)
(104)
Capitalised borrowing costs
382
334
308
Accretion expense asset retirement obligations
(449)
(453)
(412)
Interest expense current financial liabilities and other
 
finance expense
(192)
(114)
(232)
Interest expenses and other finance expenses
(1,379)
(1,223)
(1,392)
Net financial items
(207)
(2,080)
(836)
Equinor's main financial items relate to assets and liabilities categorised in the fair value through
 
profit or loss and the amortised cost
categories. For more information about financial instruments by category see note 28 Financial instruments
 
and fair value
measurement.
Foreign currency exchange gains/(losses) derivative financial instruments include fair value changes
 
of currency derivatives related to
liquidity and currency risk. The line item Other foreign currency exchange gains/(losses) includes
 
a fair value loss from derivatives
related to non-current debt of USD 691 million in 2022, a loss of USD 702 million
 
in 2021 and a gain of USD 796 million in 2020.
The line item Gains/(losses) other derivative financial instruments primarily includes fair value changes from interest
 
rate related
derivatives, with a loss of USD 1,760 million and USD 724 million in 2022 and
 
2021 respectively, and a gain of USD 432 million in
2020.
The line item Interest expense bonds and bank loans and net interest on related derivatives includes
 
interest expenses of USD 918
million, USD 990 million, and USD 1,031 million for 2022, 2021 and 2020, respectively, from the financial liabilities at amortised cost
category. It also includes net interest on related derivatives from the fair value through profit or loss category, amounting to a net
interest expense of USD 111
 
million for 2022, net interest income of USD 94 million and USD 79 million for
 
2021 and 2020,
respectively.
 
Equinor, Annual Report on Form 20-F 2022
 
183
11 Income
 
taxes
Accounting policies
 
Income tax
Income tax in the Consolidated statement of income comprises current and deferred tax expense. Income
 
tax is recognised in the
Consolidated statement of income except when it relates to items recognised in OCI.
Current tax consists of the expected tax payable on the taxable income for the year and any
 
adjustment to tax payable for previous
years. Uncertain tax positions and potential tax exposures are analysed individually. The outcomes of tax disputes are mostly binary
in nature, and in each case the most likely amount for probable liabilities to be paid (including penalties)
 
or assets to be received
(disputed tax positions for which payment has already been made) is recognised within Current
 
tax or Deferred tax as appropriate.
Uplift benefit on the NCS is recognised when the deduction is included in the
 
current year tax return and impacts taxes payable.
Deferred tax assets and liabilities are recognised for the future tax consequences attributable to
 
differences between the carrying
amounts of existing assets and liabilities and their respective tax bases, and on unused tax losses
 
and credits carried forward, subject
to the initial recognition exemption. A deferred tax asset is recognised only to the extent that it is
 
probable that future taxable income
will be available against which the asset can be utilised. For a deferred tax asset to be recognised
 
based on future taxable income,
convincing evidence is required, considering the existence of contracts, production of oil or gas in the
 
near future based on volumes of
expected reserves, observable prices in active markets, expected volatility of trading profits,
 
expected foreign currency rate
movements and similar facts and circumstances.
When an asset retirement obligation or a lease contract is initially reflected in the accounts, a deferred
 
tax liability and a corresponding
deferred tax asset are recognised simultaneously and accounted for in line with other deferred tax items.
 
The applied policy is in line
with an amendment to IAS 12 Income Taxes,
 
reducing the scope of the initial recognition exemption, which is effective from 1 January
2023.
Estimation uncertainty regarding income tax
Equinor incurs significant amounts of income taxes payable to various jurisdictions and may
 
recognise significant changes to deferred
tax assets and deferred tax liabilities. There may be uncertainties related to interpretations
 
of applicable tax laws and regulations
regarding amounts in Equinor’s tax returns, which are filed in a number
 
of tax regimes. For cases of uncertain tax treatments, it may
take several years to complete the discussions with relevant tax authorities or to reach resolutions
 
of the appropriate tax positions
through litigation.
The carrying values of income tax related assets and liabilities are based on Equinor's interpretations
 
of applicable laws, regulations
and relevant court decisions. The quality of these estimates, including the most likely outcomes
 
of uncertain tax treatments, is
dependent upon proper application of at times very complex sets of rules, the recognition of changes
 
in applicable rules and, in the
case of deferred tax assets, management's ability to project future earnings from activities that may apply loss
 
carry forward positions
against future income taxes. Climate-related matters and the transition to carbon-neutral
 
energy-consumption globally have increased
the uncertainty in determining key business assumptions used to assess the recoverability
 
of deferred tax assets through sufficient
future taxable income before tax losses expire.
-----------------------------------------------------------------------------------------------------------------------------------
 
 
 
 
 
 
 
 
 
 
 
 
 
 
184
 
Equinor, Annual Report on Form 20-F 2022
 
Significant components of income tax expense
Full year
(in USD million)
2022
2021
2020
Current income tax expense in respect of
 
current year
(52,124)
(21,271)
(1,115)
Prior period adjustments
(112)
(28)
313
Current income tax expense
(52,236)
(21,299)
(802)
Origination and reversal of temporary differences
(2,136)
(1,778)
(648)
Recognition of previously unrecognised deferred
 
tax assets
4,401
126
130
Change in tax regulations
0
4
(12)
Prior period adjustments
110
(60)
94
Deferred tax income/(expense)
2,375
(1,708)
(435)
Income tax
(49,861)
(23,007)
(1,237)
Changes to tax regimes
Norway
As a measure to maintain activity in the oil and gas related industry during the Covid-19
 
pandemic, the Norwegian Government
enacted temporary targeted changes to Norway’s petroleum tax system for investments incurred in 2020 and 2021, and
 
for new
projects with Plan for development and operations (PDOs) or Plan for installation and
 
operations (PIOs) submitted to the Ministry of
Oil and Energy by the end of 2022 and approved prior to 1 January 2024. The changes were effective from
 
1 January 2020 and
provided companies with a direct tax deduction in the special petroleum tax instead of
 
tax depreciation over six years. In addition, the
tax uplift benefit, was recognised over one year instead of four years. Tax depreciation towards the ordinary offshore corporate tax
was continued
 
with a six-year depreciation profile.
 
On 17 June 2022, the Norwegian Parliament adopted amendments to the Petroleum Tax Act to convert the special tax for petroleum
activities to a cash flow tax. The amendments were effective 1 January 2022 and maintains the marginal rate for
 
special petroleum tax
and corporate income tax at 56% and 22% respectively but allows for cost of investments in the year of
 
investment and calculated
corporate income tax to be deducted in the special petroleum tax base. Uplift deductions for
 
investments incurred after 1 January
2022 was discontinued. The uplift deduction rate under the temporary rules was reduced to 17.69%
 
for 2022 and further reduced to
12.4% as from 2023.
 
UK
On 23 May 2022, the UK introduced a new levy intended to tax windfall profits on oil and gas production from the
 
United Kingdom
Continental Shelf, called the Energy (Oil & Gas) Profits Levy Act 2022 (EPL).
EPL was introduced as a new temporary tax at the rate of 25% from 26 May 2022 to 31 December
 
2022, and further increased to
35% from 1 January 2023 to 31 March 2028. It applies to profits on transactions from that date forward
 
with no tax relief for prior
expenditures or brought forward losses and with no EPL tax relief for interest and
 
decommissioning costs. Capital cost incurred since
26 May 2022 are eligible for an EPL deductible uplift of 80% until 31 December 2022
 
and thereafter at 29% for expenditure other than
that in respect of de-carbonisation where the rate of uplift remains at 80%. EPL losses
 
can be carried forward without limitation and
carried back for one year.
 
US
On August 16, 2022, the Inflation Reduction Act (IRA) was enacted in the USA. As
 
from 2023, under the IRA a Corporate Minimum
Tax on Book Earnings (BMT) applies a 15% tax on adjusted financial statement income. The enactment of the IRA had no impact in
2022.
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
185
Reconciliation of statutory tax rate to effective
 
tax rate
Full year
(in USD million)
2022
2021
2020
Income/(loss) before tax
78,604
31,583
(4,259)
Calculated income tax at statutory rate
1)
(18,168)
(7,053)
1,445
Calculated Norwegian Petroleum tax
2)
(36,952)
(17,619)
(2,126)
Tax effect uplift
3)
259
914
1,006
Tax effect of permanent differences regarding divestments
417
90
(9)
Tax effect of permanent differences caused by functional currency different from tax currency
145
150
(198)
Tax effect of other permanent differences
403
228
450
Recognition of previously unrecognised deferred
 
tax assets
4)
4,401
126
130
Change in unrecognised deferred tax assets
(34)
619
(1,685)
Change in tax regulations
0
4
(12)
Prior period adjustments
(3)
(88)
408
Other items including foreign currency effects
(327)
(378)
(647)
Income tax
(49,861)
(23,007)
(1,237)
Effective tax rate
63.4 %
72.8 %
(29.0 %)
1)
 
The weighted average of statutory tax rates was 23.1% in 2022, 22.3% in 2021 and 33.9% in 2020. The rates
 
are influenced by
earnings composition between tax regimes with lower statutory tax rates and tax regimes with higher statutory
 
tax rates.
2)
 
The Norwegian petroleum income is taxable at a tax rate of 71.8% after deduction for 22% corporate tax
 
in the special petroleum
tax basis.
3)
 
When calculating the petroleum tax of 71.8% on income from the Norwegian continental shelf,
 
an additional tax-free allowance
(uplift) was previously granted on the basis of the original capitalised cost of
 
offshore production installations.
Previously, a 5.2% uplift could be deducted from taxable income for a period of four years starting when the capital expenditure
was incurred. On 17 June 2022, the Norwegian Parliament adopted amendments to the Petroleum
 
Tax Act and converted the
special tax for petroleum activities to a cash flow tax. The amendments were effective 1 January 2022. Uplift
 
deductions for
investments incurred after 1 January 2022 were discontinued. At year-end 2022, un-recognised uplift credits were
 
zero,
compared to USD 272 million at year-end 2021.
For 2020 and 2021, temporary rules enacted under the Covid-19 pandemic allowed direct deduction of the whole
 
uplift at a rate
of 24% in the year the capital expenditure was incurred. This rate was reduced to 17.69%
 
for 2022, and further reduced to 12.4%
on capital expenditures incurred on investments eligible under the temporary rules as from 2023.
4)
 
An amount of USD 4,401 million of previously un-recognised deferred tax assets was recognised
 
in 2022, resulting in a lower
effective tax rate for 2022 compared to 2021. More than 90% of the recognition relates to the US, that
 
after a history of significant
losses, is now recording profits. Projected future taxable income demonstrates that it is probable that the
 
unused tax losses
carried forward can be utilised in the nearest future. The tax value of unused accumulated losses recognised
 
as a deferred tax
asset in the US, amounts to USD 2,738 million at year-end 2022.
 
A 30% decline in commodity prices, considered to represent a
reasonably possible change, would have an immaterial impact on the recognised amount.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
186
 
Equinor, Annual Report on Form 20-F 2022
 
Deferred tax assets and liabilities comprise
(in USD million)
Tax losses
carried
forward
Property,
plant and
equipment
 
and
intangible
assets
Asset
retirement
obligations
Lease
liabilities
Pensions
Derivatives
Other
Total
Deferred tax assets
8,105
694
7,356
1,306
694
1,131
1,348
20,634
Deferred tax liabilities
(28)
(23,356)
0
(3)
(12)
(3)
(411)
(23,813)
Net asset/(liability) at 31 December
2022
8,077
(22,662)
7,356
1,303
682
1,128
937
(3,179)
Deferred tax assets
5,162
719
11,256
1,506
804
21
2,015
21,484
Deferred tax liabilities
0
(27,136)
0
0
(21)
(1,453)
(530)
(29,140)
Net asset/(liability) at 31 December
2021
5,162
(26,417)
11,256
1,506
783
(1,432)
1,485
(7,655)
Changes in net deferred tax liability during
 
the year were as follows:
(in USD million)
2022
2021
2020
Net deferred tax liability at 1 January
7,655
6,250
5,530
Charged/(credited) to the Consolidated statement of
 
income
(2,375)
1,708
435
Charged/(credited) to Other comprehensive income
105
35
(19)
Acquisitions and disposals
(968)
36
0
Foreign currency translation effects and other effects
(1,239)
(374)
304
Net deferred tax liability at 31 December
3,179
7,655
6,250
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
187
Deferred tax assets and liabilities are offset to the extent that the deferred taxes relate to the same fiscal
 
authority, and there is a
legally enforceable right to offset current tax assets against current tax liabilities. After netting deferred tax assets and
 
liabilities by
fiscal entity and reclassification to Assets held for sale, deferred taxes are presented on the Consolidated
 
balance sheet as follows:
At 31 December
(in USD million)
2022
2021
Deferred tax assets
8,732
6,259
Deferred tax liabilities
11,996
14,037
Deferred tax assets reported in Assets classified as
 
held for sale
85
122
Deferred tax assets are recognised based on the expectation that sufficient taxable income will be available
 
through reversal of
taxable temporary differences or future taxable income. At year-end 2022, the deferred tax assets of USD 8,817 million were
 
primarily
recognised in the US, the UK, Norway, Angola, Canada and Brazil. Of this amount, USD 1,953 million was recognised in entities
which have suffered a tax loss in either the current or the preceding period. The corresponding amounts for 2021, were
 
USD 6,381
million and USD 4,636 million, respectively.
 
The tax losses will be utilised through reversal of taxable temporary differences and future
taxable income,
 
mainly from production of oil and gas.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
188
 
Equinor, Annual Report on Form 20-F 2022
 
Unrecognised deferred tax assets
At 31 December
2022
2021
(in USD million)
Basis
Tax
Basis
Tax
Deductible temporary differences
2,558
968
2,900
1,203
Unused tax credits
0
129
0
264
Tax losses carried forward
3,458
930
20,552
5,047
Total unrecognised deferred tax assets
6,016
2,027
23,452
6,514
Approximately 90% of the unrecognised carry forward tax losses can be carried forward indefinitely. The majority of the unrecognised
tax losses that cannot be carried forward indefinitely expire after 2027. The unrecognised tax credits expire from
 
2030, while the
unrecognised deductible temporary differences do not expire under the current tax legislation. Deferred tax assets have
 
not been
recognised in respect of these items because currently there is insufficient evidence to support that future taxable
 
profits will be
available to secure utilisation of the benefits.
At year-end 2022, unrecognised deferred tax assets in Angola and Canada represents USD
 
636 million and USD 346 million,
respectively, of the total unrecognised deferred tax assets of USD 2,027 million. Similar amounts for 2021 were USD 4,206 million in
the USA and USD 749 million in Angola, respectively, of a total of USD 6,514 million. The remaining unrecognised deferred tax assets
originate from several different tax jurisdictions.
 
 
Equinor, Annual Report on Form 20-F 2022
 
189
12 Property,
 
plant and equipment
Accounting policies
Property, plant and equipment
Property, plant and equipment is reflected at cost, less accumulated depreciation and impairment. The initial cost of an asset
comprises its purchase price or construction cost, any costs directly attributable to bringing the asset into operation,
 
the initial estimate
of an asset retirement obligation, exploration costs transferred from intangible assets and, for
 
qualifying assets, borrowing costs.
Proceeds from production ahead of a project’s final approval are regarded as ‘early production’ and is
 
recognised as revenue rather
than as a reduction of acquisition cost. Contingent consideration included in the acquisition
 
of an asset or group of similar assets is
initially measured at its fair value, with later changes in fair value other than due
 
to the passage of time reflected in the book value of
the asset or group of assets, unless the asset is impaired. Property, plant and equipment include costs relating to expenditures
incurred under the terms of production sharing agreements (PSAs) in certain countries, and which qualify for
 
recognition as assets of
Equinor. State-owned entities in the respective countries, however, normally hold the legal title to such PSA-based property, plant and
equipment.
Expenditure on major maintenance refits or repairs comprises the cost of replacement assets
 
or parts of assets, inspection costs and
overhaul costs. Inspection and overhaul costs, associated with regularly scheduled major maintenance programmes
 
planned and
carried out at recurring intervals exceeding one year, are capitalised and amortised over the period to the next scheduled inspection
and overhaul. All other maintenance costs are expensed as incurred.
Capitalised exploration and evaluation expenditures, development expenditure on the construction,
 
installation or completion of
infrastructure facilities such as platforms, pipelines and the drilling of production wells, and field-dedicated transport
 
systems for oil
and gas are capitalised as Producing oil and gas properties within Property, plant and equipment. Such capitalised costs, when
designed for significantly larger volumes than the reserves from already developed and producing
 
wells, are depreciated using the
unit of production method (UoP) based on proved reserves expected to be recovered from the
 
area during the concession or contract
period. Depreciation of production wells uses the UoP method based on proved developed reserves,
 
and capitalised acquisition costs
of proved properties are depreciated using the UoP method based on total proved reserves. In the
 
rare circumstances where the use
of proved reserves fails to provide an appropriate basis reflecting the pattern in which the
 
asset’s future economic benefits are
expected to be consumed, a more appropriate reserve estimate is used. Depreciation of other assets
 
and transport systems used by
several fields is calculated on the basis of their estimated useful lives, normally using the straight-line method.
 
Each part of an item of
property, plant and equipment with a cost that is significant in relation to the total cost of the item is depreciated separately. For
exploration and production assets, Equinor has established separate depreciation categories
 
which as a minimum distinguish
between platforms, pipelines and wells.
The estimated useful lives of property, plant and equipment are reviewed on an annual basis, and changes in useful lives are
accounted for prospectively. An item of property, plant and equipment is derecognised upon disposal. Any gain or loss arising on
derecognition of the asset is included in Other income or Operating expenses, respectively, in the period the item is derecognised.
Monetary or non-monetary grants from governments, when related to property, plant and equipment and considered reasonably
certain, are recognised in the Consolidated balance sheet as a deduction to the carrying
 
value of the asset and subsequently
recognised in the Consolidated statement of income over the life of the depreciable asset
 
as a reduced depreciation expense.
Research and development
Equinor undertakes research and development both on a funded basis for licence holders
 
and on an unfunded basis for projects at its
own risk, developing innovative technologies to create opportunities and enhance the value of current
 
and future assets. Expenses
relate both to in-house resources and the use of suppliers. Equinor's own share of the licence
 
holders' funding and the total costs of
the unfunded projects are considered for capitalisation under the applicable IFRS
 
requirements. Subsequent to initial recognition, any
capitalised development costs are accounted for in the same manner as Property, plant and equipment. Costs not qualifying for
capitalisation are expensed as incurred, see note 9 Auditor’s remuneration
 
and Research and development expenditures for more
details.
Estimation uncertainty regarding determining oil and gas reserves
Reserves quantities are, by definition, discovered, remaining, recoverable and economic. Recoverable oil and
 
gas quantities are
always uncertain. Estimating reserves is complex and based on a high degree of professional judgement
 
involving geological and
engineering assessments of in-place hydrocarbon volumes, the production, historical recovery and processing
 
yield factors and
installed plant operating capacity. The reliability of these estimates depends on both the quality and availability of the technical and
economic data and the efficiency of extracting and processing the hydrocarbons.
Estimation uncertainty; Proved oil and gas reserves
Proved oil and gas reserves may impact the carrying amounts of oil and gas producing assets,
 
as changes in the proved reserves, will
impact the unit of production rates used for depreciation and amortisation. Proved oil and
 
gas reserves are those quantities of oil and
gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty
 
to be economically producible
 
190
 
Equinor, Annual Report on Form 20-F 2022
 
from a given date forward, from known reservoirs, and under existing economic conditions, operating
 
methods, and government
regulations. Unless evidence indicates that renewal is reasonably certain, estimates of proved reserves
 
only reflect the period before
the contracts providing the right to operate expire. For future development projects, proved reserves
 
estimates are included only
where there is a significant commitment to project funding and execution and when relevant governmental
 
and regulatory approvals
have been secured or are reasonably certain to be secured.
Proved reserves are divided into proved developed and proved undeveloped reserves. Proved developed
 
reserves are to be
recovered through existing wells with existing equipment and operating methods, or where the
 
cost of the required equipment is
relatively minor compared to the cost of a new well. Proved undeveloped reserves are to
 
be recovered from new wells on undrilled
acreage, or from existing wells where a relatively major capital expenditure is required. Undrilled
 
well locations can be classified as
having proved undeveloped reserves if a development plan is in place indicating that they are scheduled
 
to be drilled within five years
unless specific circumstances justify a longer time horizon. Specific circumstances are for instance fields which
 
have large up-front
investments in offshore infrastructure, such as many fields on the NCS, where drilling of wells is scheduled
 
to continue for much
longer than five years. For unconventional reservoirs where continued drilling of new wells is a major
 
part of the investments, such as
the US onshore assets, the proved reserves are always limited to proved well locations
 
scheduled to be drilled within five years.
Proved oil and gas reserves have been estimated by internal qualified professionals based on industry
 
standards and are governed by
the oil and gas rules and disclosure requirements in the U.S. Securities and Exchange Commission
 
(SEC) regulations S-K and S-X,
and the Financial Accounting Standards Board (FASB) requirements for supplemental oil and gas disclosures. The estimates have
been based on a 12-month average product price and on existing economic conditions and operating
 
methods as required, and
recovery of the estimated quantities have a high degree of certainty (at least a 90% probability).
 
An independent third party has
evaluated Equinor's proved reserves estimates, and the results of this evaluation do not differ materially from Equinor's
 
estimates.
Estimation uncertainty; Expected oil and gas reserves
Changes in the expected oil and gas reserves may materially impact the amounts of asset
 
retirement obligations, as a consequence
of timing of the removal activities. It will also impact value-in-use calculations for oil and gas assets,
 
possibly affecting impairment
testing and the recognition of deferred tax assets. Expected oil and gas reserves are the estimated
 
remaining, commercially
recoverable quantities, based on Equinor's judgement of future economic conditions, from projects in
 
operation or decided for
development. As per Equinor’s internal guidelines, expected reserves are defined
 
as the ‘forward looking mean reserves’ when based
on a stochastic prediction approach. In some cases, a deterministic prediction method is used, in which
 
case the expected reserves
are the deterministic base case or best estimate. Expected reserves are therefore typically larger
 
than proved reserves as defined by
the SEC, which are high confidence estimates with at least a 90% probability of recovery
 
when a probabilistic approach is used.
Expected oil and gas reserves have been estimated by internal qualified professionals based on industry
 
standards and classified in
accordance with the Norwegian resource classification system issued by the Norwegian Petroleum
 
Directorate.
-----------------------------------------------------------------------------------------------------------------------------
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
191
(in USD million)
Machinery,
equipment and
transportation
equipment
Production
plants and oil
and gas
assets
Refining and
manufacturing
plants
Buildings
and land
Assets under
development
Right of use
assets
4)
Total
Cost at 1 January 2022
1,335
183,358
8,481
596
12,614
5,850
212,234
Additions and transfers
6)
52
9,390
378
6
(813)
1,319
10,332
Changes in asset retirement obligations
0
(4,756)
0
0
(48)
0
(4,805)
Disposals at cost
(9)
(3,487)
2
(20)
(5)
(347)
(3,865)
Foreign currency translation effects
(36)
(12,557)
(576)
(19)
(934)
(188)
(14,310)
Cost at 31 December 2022
1,343
171,948
8,285
562
10,815
6,633
199,586
Accumulated depreciation and impairment
losses at 1 January 2022
(1,188)
(137,763)
(7,926)
(320)
(344)
(2,619)
(150,159)
Depreciation
(52)
(7,643)
(160)
(33)
0
(969)
(8,856)
Impairment losses
(8)
(187)
(39)
0
(49)
(4)
(286)
Reversal of impairment losses
4
2,585
802
0
207
0
3,599
Transfers
6)
(2)
(20)
2
0
20
(8)
(8)
Accumulated depreciation and impairment
on disposed assets
8
2,002
(4)
5
0
347
2,359
Foreign currency translation effects
34
9,571
562
9
30
59
10,264
Accumulated depreciation and impairment
losses at 31 December 2022
5)
(1,203)
(131,455)
(6,763)
(338)
(135)
(3,194)
(143,088)
Carrying amount at 31 December 2022
140
40,493
1,522
224
10,679
3,439
56,498
Estimated useful lives (years)
 
3 - 20
UoP
1)
 
15 - 20
 
10 - 33
2)
 
1 - 20
3)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
192
 
Equinor, Annual Report on Form 20-F 2022
 
(in USD million)
Machinery,
equipment and
transportation
equipment
Production
plants and oil
and gas
assets
Refining and
manufacturing
plants
Buildings
and land
Assets under
development
Right of use
assets
Total
Cost at 1 January 2021
2,806
183,082
9,238
929
13,163
6,370
215,587
Additions and transfers
6)
39
9,439
95
27
(355)
148
9,393
Changes in asset retirement obligations
0
(2,125)
0
0
(40)
0
(2,165)
Disposals at cost
(1,496)
(1,975)
(70)
(353)
(25)
(501)
(4,420)
Assets reclassified to held for sale
0
(1,010)
(563)
0
0
(91)
(1,664)
Foreign currency translation effects
(13)
(4,052)
(220)
(6)
(130)
(77)
(4,497)
Cost at 31 December 2021
1,335
183,358
8,481
596
12,614
5,850
212,234
Accumulated depreciation and impairment
losses at 1 January 2021
(2,596)
(132,427)
(8,005)
(524)
(1,275)
(2,251)
(147,079)
Depreciation
(68)
(9,136)
(232)
(42)
0
(930)
(10,408)
Impairment losses
(42)
(2,092)
(401)
(21)
(390)
(17)
(2,962)
Reversal of impairment losses
0
1,675
0
0
0
2
1,677
Transfers
6)
61
(1,319)
0
(61)
1,319
(11)
(11)
Accumulated depreciation and impairment
on disposed assets
1,448
1,785
59
326
21
480
4,118
Accumulated depreciation and impairment
assets classified as held for sale
0
825
461
0
0
82
1,367
Foreign currency translation effects
9
2,926
192
2
(18)
27
3,138
Accumulated depreciation and impairment
losses at 31 December 2021
5)
(1,188)
(137,763)
(7,926)
(320)
(344)
(2,619)
(150,159)
Carrying amount at 31 December 2021
147
45,595
555
276
12,270
3,231
62,075
Estimated useful lives (years)
 
3 - 20
UoP
1)
 
15 - 20
 
10 - 33
2)
 
1 - 20
3)
1)
 
Depreciation according to unit of production method.
2)
 
Land is not depreciated
.
Buildings include leasehold improvements.
3)
 
Depreciation linearly over contract period.
4)
 
Right of use assets at 31 December 2022 mainly consist of Land and buildings USD 1,013 million, Vessels USD 1,557 million
and Drilling rigs USD 595 million.
5)
 
See note 14 Impairments.
6)
 
The carrying amount of assets transferred to Property plant and equipment from Intangible assets
in 2022 and 2021 amounted to
USD 982 million and USD 1,730 million, respectively.
 
Equinor, Annual Report on Form 20-F 2022
 
193
13 Intangible assets
Accounting policies
Intangible assets including goodwill
Intangible assets are stated at cost, less accumulated amortisation and impairment. Intangible assets include
 
acquisition cost for oil
and gas prospects, expenditures on the exploration for and evaluation of oil and natural gas
 
resources, goodwill, and other intangible
assets. Intangible assets relating to expenditures on the exploration for and evaluation of oil
 
and natural gas resources are not
amortised. When the decision to develop a particular area is made, related intangible exploration
 
and evaluation assets are
reclassified to Property, plant and equipment.
Goodwill acquired in a business combination is allocated to each cash generating unit (CGU), or
 
group of units, expected to benefit
from the combination’s synergies. Following initial recognition, goodwill is measured at cost less any accumulated impairment
 
losses.
In acquisitions made on a post-tax basis according to the rules on the NCS, a provision
 
for deferred tax is reflected in the accounts
based on the difference between the acquisition cost and the tax depreciation basis transferred from the seller. The offsetting entry to
such deferred tax amounts is reflected as goodwill, which is allocated to the CGU or group
 
of CGUs on whose tax depreciation basis
the deferred tax has been computed.
Other intangible assets with a finite useful life, are depreciated over their useful life using the straight-line
 
method.
Oil and gas exploration, evaluation and development expenditures
Equinor uses the successful efforts method of accounting for oil and gas exploration costs. Expenditures to
 
acquire mineral interests
in oil and gas properties, including signature bonuses, expenditures to drill and equip exploratory wells
 
and evaluation expenditures
are capitalised within Intangible assets as Exploration expenditures and Acquisition costs - oil and gas
 
prospects. Geological and
geophysical costs and other exploration and evaluation expenditures are expensed as incurred.
Exploration wells that discover potentially economic quantities of oil and natural gas remain
 
capitalised as intangible assets during the
evaluation phase of the discovery. This evaluation is normally finalised within one year after well completion. If, following the
evaluation, the exploratory well has not found potentially commercial quantities of hydrocarbons,
 
the previously capitalised costs are
evaluated for derecognition or tested for impairment. Any derecognition or impairment is
 
classified as Exploration expenses in the
Consolidated statement of income.
Capitalised exploration and evaluation expenditures related to offshore wells that find proved reserves, are transferred
 
to Property,
plant and equipment at the time of sanctioning of the development project. The timing from evaluation
 
of a discovery until a project is
sanctioned could take several years depending on the location and maturity, including existing infrastructure, of the area of discovery,
whether a host government agreement is in place, the complexity of the project and the
 
financial robustness of the project. For
onshore wells where no sanction is required, the transfer to Property, plant and equipment occurs at the time when a well is ready for
production.
For exploration and evaluation asset acquisitions (farm-in arrangements) in which Equinor has decided to fund
 
a portion of the selling
partner's exploration and/or future development expenditures (carried interests), these expenditures are reflected in
 
the Consolidated
financial statements as and when the exploration and development work progresses.
Equinor reflects exploration and evaluation asset disposals (farm-out arrangements) on a historical cost basis with no gain
 
or loss
recognition. Consideration from the sale of an undeveloped part of an asset reduces the carrying
 
amount of the asset. If the
consideration exceeds the carrying amount of the asset, the excess amount is reflected in the Consolidated
 
statement of income
under Other income. Equal-valued exchanges (swaps) of exploration and evaluation assets with
 
only immaterial cash considerations
are accounted for at the carrying amounts of the assets given up with no gain or loss recognition.
Estimation uncertainty regarding exploration activities
Exploratory wells that have found reserves, but where classification of those reserves as proved
 
depends on whether a major capital
expenditure can be justified, will remain capitalised during the evaluation phase for the findings
 
on the exploration wells. Thereafter it
will be considered a trigger for impairment evaluation of the well if no development decision is
 
planned for the near future, and there
moreover are no concrete plans for future drilling in the licence. Judgements as to whether these
 
expenditures should remain
capitalised, be derecognised or impaired in the period may materially affect the carrying values of these assets and consequently, the
operating income for the period.
------------------------------------------------------------------------------------------------------------------------------
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
194
 
Equinor, Annual Report on Form 20-F 2022
 
(in USD million)
Exploration
expenses
Acquisition
costs - oil and
gas prospects
Goodwill
Other
Total
Cost at 1 January 2022
1,958
2,670
1,467
722
6,816
Additions
227
4
36
57
324
Disposals at cost
(10)
(50)
0
1
(58)
Transfers
(227)
(516)
0
(239)
(982)
Expensed exploration expenditures previously capitalised
(283)
(59)
0
0
(342)
Impairment of goodwill
0
0
(3)
0
(3)
Foreign currency translation effects
(65)
(14)
(121)
(13)
(213)
Cost at 31 December 2022
1,599
2,035
1,380
528
5,542
Accumulated depreciation and impairment losses
 
at 31 December
2022
1)
(384)
(384)
Carrying amount at 31 December 2022
1,599
2,035
1,380
144
5,158
(in USD million)
Exploration
expenses
Acquisition
costs - oil and
gas prospects
Goodwill
Other
Total
Cost at 1 January 2021
2,261
3,932
1,481
831
8,505
Additions
191
36
61
90
378
Disposals at cost
(22)
1
(3)
(29)
(53)
Transfers
(432)
(1,137)
0
(161)
(1,730)
Expensed exploration expenditures previously capitalised
(19)
(152)
0
0
(171)
Impairment of goodwill
0
0
(1)
0
(1)
Foreign currency translation effects
(21)
(10)
(70)
(10)
(111)
Cost at 31 December 2021
1,958
2,670
1,467
722
6,816
Accumulated depreciation and impairment losses
 
at 31 December
2021
1)
(364)
(364)
Carrying amount at 31 December 2021
1,958
2,670
1,467
358
6,452
1) See note 14 Impairments.
Goodwill of USD 1,380 million per 31 December 2022 mainly consist of technical goodwill related
 
to business acquisitions in 2019,
USD 550 million in the Exploration & Production Norway area and USD 410 million in the
 
Marketing Midstream & Processing area.
The table below shows the aging of capitalised exploration expenditures.
(in USD million)
2022
2021
Less than one year
250
234
Between one and five years
340
692
More than five years
1,009
1,033
Total capitalised exploration expenditures
1,599
1,958
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
195
The table below shows the components of the exploration
 
expenses.
Full year
(in USD million)
2022
2021
2020
Exploration expenditures
1,087
1,027
1,371
Expensed exploration expenditures previously capitalised
342
171
2,506
Capitalised exploration
(224)
(194)
(394)
Exploration expenses
1,205
1,004
3,483
14 Impairments
Accounting policies
Impairment of property, plant and equipment, right-of-use assets and intangible assets including goodwill
Equinor assesses individual assets or groups of assets for impairment whenever events or changes in
 
circumstances indicate that the
carrying value of an asset may not be recoverable. Assets are grouped into cash generating units (CGUs)
 
which are the smallest
identifiable groups of assets that generate cash inflows that are largely independent of the
 
cash inflows from other groups of assets.
Normally, separate CGUs are individual oil and gas fields or plants. Each unconventional asset play is considered a single CGU when
no cash inflows from parts of the play can be reliably identified as being largely independent
 
of the cash inflows from other parts of the
play. In impairment evaluations, the carrying amounts of CGUs are determined on a basis consistent with that of the recoverable
amount.
Unproved oil and gas properties are assessed for impairment when facts and circumstances
 
suggest that the carrying amount of the
asset or CGU to which the unproved properties belong may exceed its recoverable amount,
 
and at least once a year. Exploratory
wells that have found reserves, but where classification of those reserves as proved depends on
 
whether major capital expenditure
can be justified or where the economic viability of that major capital expenditure depends on the successful
 
completion of further
exploration work, will remain capitalised during the evaluation phase for the exploratory finds.
 
If, following evaluation, an exploratory
well has not found proved reserves, the previously capitalised costs are tested for impairment. After the
 
initial evaluation phase for a
well, it will be considered a trigger for impairment testing of a well if no development
 
decision is planned for the near future and there
is no firm plan for future drilling in the licence.
Goodwill is reviewed for impairment annually or more frequently if events or changes in circumstances
 
indicate that the carrying value
may be impaired. Impairment is determined by assessing the recoverable amount of the CGU,
 
or group of units, to which the goodwill
relates. When impairment testing goodwill originally recognised as an offsetting item to the computed deferred
 
tax provision in a post-
tax transaction on the NCS, the remaining amount of the deferred tax provision will factor
 
into the impairment evaluations.
Impairment losses and reversals of impairment losses are presented in the Consolidated statement
 
of income as Exploration
expenses or Depreciation, amortisation and net impairment losses, on the basis of the nature of the impaired
 
assets as either
exploration assets (intangible exploration assets) or development and producing assets (property, plant and equipment and other
intangible assets), respectively.
Measurement
The recoverable amount applied in Equinor’s impairment assessments is normally estimated value
 
in use. Equinor may also apply the
assets’ fair value less cost of disposal as the recoverable amount when such a value is available,
 
reasonably reliable,
 
and based on a
recent and comparable transaction.
Value in use is determined using a discounted cash flow model. The estimated future cash flows are based on reasonable and
supportable assumptions and represent management's best estimates of the range of economic
 
conditions that will exist over the
remaining useful life of the assets, as set down in Equinor's most recently approved forecasts.
 
Assumptions and economic conditions
in establishing the forecasts are reviewed by management on a regular basis and updated at least annually. For assets and CGUs
with an expected useful life or timeline for production of expected oil and natural gas reserves
 
extending beyond five years, including
planned onshore production from shale assets with a long development and production horizon, the forecasts
 
reflect expected
production volumes, and the related cash flows include project or asset specific estimates reflecting
 
the relevant period. Such
estimates are established based on Equinor's principles and assumptions and are consistently applied.
The estimated future cash flows are adjusted for risks specific to the asset or CGU and discounted
 
using a real post-tax discount rate
which is based on Equinor's post-tax weighted average cost of capital (WACC). Country risk specific to a project is included as a
monetary adjustment to the projects’ cash flow. Equinor considers country risk primarily as an unsystematic risk. The cash flow is
adjusted for risk that influences the expected cash flow of a project and which is not part of the
 
project itself. The use of post-tax
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
196
 
Equinor, Annual Report on Form 20-F 2022
 
discount rates in determining value in use does not result in a materially different determination of the need for, or the amount of,
impairment that would be required if pre-tax discount rates had been used.
Impairment reversals
A previously recognised impairment loss is reversed only if there has been a change in the estimates used to
 
determine the asset’s
recoverable amount since the last impairment loss was recognised. A reversal cannot exceed the
 
carrying amount of the asset or
CGU that would have been reflected, net of depreciation, if no impairment loss had been recognised
 
in prior periods. Impairment of
unsuccessful wells is reversed only to the extent that conditions for impairment are no longer present.
 
Previously recognised
impairments of goodwill are not reversed in future periods.
Estimation uncertainty regarding impairment
Evaluating whether an asset is impaired or if an impairment should be reversed requires a
 
high degree of judgement and may to a
large extent depend upon the selection of key assumptions about the future. In Equinor's
 
line of business, judgement is involved in
determining what constitutes a CGU. Development in production, infrastructure solutions, markets, product
 
pricing, management
actions and other factors may over time lead to changes in CGUs such as splitting one original
 
CGU into several CGUs.
The key assumptions used will bear the risk of change based on the inherent volatile nature of macro-economic
 
factors such as future
commodity prices and discount rates, and uncertainty in asset specific factors such as reserve
 
estimates and operational decisions
impacting the production profile or activity levels for our oil and natural gas properties. Changes in foreign
 
currency exchange rates
will also affect value in use, especially for assets on the NCS, where the functional currency is NOK. When estimating
 
the recoverable
amount, the expected cash flow approach is applied to reflect uncertainties in timing and amounts inherent
 
in the assumptions used in
the estimated future cash flows. For example, climate-related matters (see also Note 3 Consequences of initiatives
 
to limit climate
changes) are expected to have a pervasive effect on the energy industry, affecting not only supply, demand and commodity prices,
but also technology changes, increased emission-related levies,
 
and other matters with mainly mid-term and long-term effects. These
effects have been factored into the price assumptions used for estimating future cash flows using probability-weighted
 
scenario
analyses.
The estimated future cash flows, reflecting Equinor’s, market participants’ and other external
 
sources’ assumptions about the future
and discounted to their present value, involve complexity. In order to establish relevant future cash flows, impairment testing requires
long-term assumptions to be made concerning a number of economic factors such as future market prices,
 
refinery margins, foreign
currency exchange rates and future output, discount rates, impact of the timing of tax incentive
 
regulations, and political and country
risk among others. Long-term assumptions for major economic factors are made at a group level, and
 
there is a high degree of
reasoned judgement involved in establishing these assumptions, in determining other relevant factors
 
such as forward price curves, in
estimating production outputs, and in determining the ultimate terminal value of an asset.
------------------------------------------------------------------------------------------------------------------------------
Net impairments/(reversal of impairments)
Full year
Property, plant and equipment
 
Intangible assets
 
Total
(in USD million)
2022
2021
2020
2022
2021
2020
2022
2021
2020
Producing and development assets
1)
(3,313)
1,285
5,671
(26)
(2)
680
(3,339)
1,283
6,351
Goodwill
1)
3
1
42
3
1
42
Other intangible assets
1)
0
0
8
0
0
8
Acquisition costs related to oil and gas prospects
2)
85
154
657
85
154
657
Total net impairments/(reversals) recognised for
Property, plant and equipment and Intangible assets
(3,313)
1,285
5,671
62
154
1,386
(3,251)
1,439
7,057
1)
 
In addition, impairments in 2022 related to equity accounted investments amounted to USD 832
 
million, please refer to note 6
Acquisitions and disposals regarding the effects of the decision to exit Russia. The total net impairment reversals recognised
 
under
IAS 36 Impairment of assets in 2022 amount to USD 2,504 million.
 
2)
 
Subject to impairment assessment under the successful efforts’ method (IFRS 6 Exploration and Evaluation
 
of Mineral Resources)
and classified as exploration expenses in the income statement.
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
197
For impairment purposes, the asset’s carrying amount is compared to its recoverable amount. The table below describes,
 
per area,
the Producing and development assets being impaired/(reversed),
 
net impairment/(reversal), and the carrying amount after
impairment.
At 31 December 2022
At 31 December 2021
(in USD million)
Carrying
amount after
impairment
 
Net impairment
loss/ (reversal)
Carrying
amount after
impairment
 
Net impairment
loss/ (reversal)
Exploration & Production Norway
3,201
(819)
5,379
(1,102)
Exploration & Production USA - onshore
546
(204)
1,979
48
Exploration & Production USA - offshore Gulf of Mexico
2,691
(882)
798
18
Europe and Asia
1,551
295
1,566
1,609
Marketing, Midstream & Processing
1,416
(895)
868
716
Other
30
0
20
(7)
Total
9,435
(2,505)
10,611
1,283
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
198
 
Equinor, Annual Report on Form 20-F 2022
 
Exploration & Production Norway
In 2022, the net impairment reversal was mainly caused by increased price estimates and changed
 
gas export strategy. In 2021, the
net impairment reversal was mainly due to increased price estimates and an upward reserve revision.
Exploration & Production USA - onshore
In 2022, the impairment reversal was caused by increased gas price assumptions,
 
while in 2021 the net impairment was caused by
revision of reserves and sale of an asset.
Exploration & Production USA - offshore Gulf of Mexico
In 2022, the impairment reversal was caused by increased price assumptions and higher reserves estimates, while
 
in 2021, the
impairment was due to a negative reserve revision.
Exploration & Production International – Europe and Asia
In 2022, the net impairment was mainly caused by the decision to exit Russia (see note 6 Acquisitions
 
and disposals). This was to a
large extent offset by a reversal on Mariner in the UK mainly due to optimisation of the production
 
profile and higher prices, supported
by a slight increase in reserves estimates. In 2021, the net impairment was mainly caused by downward
 
reserve revisions partially
offset by higher prices.
Marketing, Midstream & Processing
In 2022 the net impairment reversal was mainly related to increased refinery margin assumptions,
 
while in 2021, the impairment
losses were caused by increased CO
2
 
fees and – quotas on a refinery and a classification to held for sale.
Accounting assumptions
Management’s future commodity price assumptions and currency assumptions are applied when estimating value in
 
use. While there
are inherent uncertainties in the assumptions, the commodity price assumptions as well
 
as currency assumptions reflect
management’s best estimate of the price and currency development over the life of the Group’s assets based on its view of relevant
current circumstances and the likely future development of such circumstances, including energy demand
 
development, energy and
climate change policies as well as the speed of the energy transition, population and economic growth,
 
geopolitical risks, technology
and cost development and other factors. Management’s best estimate also takes into consideration a range of external
 
forecasts.
Equinor has performed a thorough and broad analysis of the expected development in drivers for
 
the different commodity markets and
exchange rates. Significant uncertainty exists regarding future commodity price development due to the
 
transition to a lower carbon
economy, future supply actions by OPEC+ and other factors. The management’s analysis of the expected development in drivers for
the different commodity markets and exchange rates resulted in changes in the long-term price assumptions with effect from the third
quarter of 2022. The main changes with effect for impairment and impairment reversal assessments are disclosed
 
in the table below
as price-points on price-curves. Previously applied price-points from the third quarter of 2021 up
 
to and including the second quarter
of 2022 are provided in brackets.
Year
Prices in real term 1)
2025
2030
2040
2050
Brent Blend (USD/bbl)
75
(70)
75
(75)
70
(69)
65
(64)
European gas (USD/MMBtu) - TTF
 
2)
20.0
(7.3)
9.5
(6.8)
9.0
(8.2)
9.0
(7.5)
Henry Hub (USD/MMBtu)
4.0
(3.3)
3.7
(3.4)
3.7
(3.6)
3.7
(3.6)
Electricity Germany (EUR/MWh)
115
(65)
70
(62)
57
(64)
57
(64)
EU ETS (EUR/tonne)
80
(61)
80
(70)
105
(89)
130
(108)
1)
 
Basis year 2022. The prices in the table are price-points on price-curves.
2)
As from the third quarter 2022, TTF is applied as the main reference price for European
 
gas. Updated price-points for the
previously applied NBP correspond to the disclosed updated price-points for TTF. Previously applied comparable prices for
NBP are 7.4, 6.9, 8.3 and 7.6 for 2025, 2030, 2040 and 2050 respectively.
Climate considerations are included in the impairment calculations directly by estimating the CO
2
 
taxes in the cash flows. Indirectly,
the expected effect of climate change is also included in the estimated commodity prices where supply and
 
demand are considered.
The prices also have effect on the estimated production profiles and economic cut-off of the projects. Furthermore, climate
considerations are a part of the investment decisions following Equinor’s strategy
 
and commitments to the energy transition.
Norway’s Climate Action Plan for the period 2021-2030 (Meld. St 13 (2020-2021)) which assumes
 
a gradually increased CO
2
 
tax (the
total of EU ETS + Norwegian CO
2
 
tax) in Norway to 2,000 NOK/tonne in 2030 is used for impairment calculations of Norwegian
upstream assets.
Equinor, Annual Report on Form 20-F 2022
 
199
To reflect that carbon will have a cost for all our assets the current best estimate is considered to be EU ETS for countries outside EU
where carbon is not already subject to taxation or where Equinor has not established specific estimates.
The long-term NOK currency exchange rates are expected to be unchanged compared to previous
 
long-term assumptions. The
NOK/USD rate from 2025 and onwards is kept at 8.50, the NOK/EUR at 10.0. The USD/GBP
 
rate is kept at 1.35.
The base discount rate applied in value in use calculations is 5.0% real after tax. The discount rate
 
is derived from Equinor’s weighted
average cost of capital. For projects, mainly within the REN segment in periods with fixed low
 
risk income,
 
a lower discount rate will be
considered. A derived pre-tax discount rate is in the range of 42-102% for E&P Norway, 8-9% for E&P International, 6-9% for E&P
USA and 7% for MMP depending on the asset’s characteristics, such as specific tax treatments, cash flow
 
profiles, and economic life.
The pre-tax rates for 2021 were 18-32%, 5-9%, 6-7% and 7% respectively.
Sensitivities
Commodity prices have historically been volatile. Significant downward adjustments of Equinor’s
 
commodity price assumptions would
result in impairment losses on certain producing and development assets in Equinor’s
 
portfolio including intangible assets that are
subject to impairment assessment, while an opposite adjustment could lead to impairment-reversals. If
 
a decline in commodity price
forecasts over the lifetime of the assets was 30%, considered to represent a reasonably possible change,
 
the impairment amount to
be recognised could illustratively be in the region of USD 14 billion before tax effects. See note 3 Consequences of
 
initiatives to limit
climate changes for possible effect of using the prices in a 1.5
o
C compatible Net Zero Emission by 2050 scenario and the Announced
Pledges Scenario as estimated by the International Energy Agency (IEA).
These illustrative impairment sensitivities, both based on a simplified method, assumes no changes
 
to input factors other than prices;
however, a price reduction of 30% or those representing Net Zero Emission scenario and Announced Pledges Scenario is likely
 
to
result in changes in business plans as well as other factors used when estimating an asset’s recoverable
 
amount. These associated
changes reduce the stand-alone impact on the price sensitivities. Changes in such input factors would likely include
 
a reduction in the
cost level in the oil and gas industry as well as offsetting foreign currency effects, both of which have historically occurred following
significant changes in commodity prices. The illustrative sensitivities are therefore not considered to
 
represent a best estimate of an
expected impairment impact, nor an estimated impact on revenues or operating income in such
 
a scenario. A significant and
prolonged reduction in oil and gas prices would also result in mitigating actions by Equinor and its
 
licence partners, as a reduction of
oil and gas prices would impact drilling plans and production profiles for new and existing assets.
 
Quantifying such impacts is
considered impracticable, as it requires detailed technical, geological and economical evaluations
 
based on hypothetical scenarios
and not based on existing business or development plans.
200
 
Equinor, Annual Report on Form 20-F 2022
 
15 Joint arrangements and associates
Accounting policies
Joint operations and similar arrangements, joint ventures and associates
A joint arrangement is a contractual arrangement whereby Equinor and other parties undertake an
 
activity subject to joint control, i.e.
when decisions about the relevant activities require the unanimous consent of the parties
 
sharing control. Such joint arrangements are
classified as either joint operations or joint ventures. In determining the appropriate classification, Equinor
 
considers the nature of
products and markets of the arrangements and whether the substance of the agreements is
 
that the parties involved have rights to
substantially all the arrangement's assets and obligations for the liabilities, or whether the parties involved have
 
rights to the net
assets of the arrangement. Equinor accounts for its share of assets, liabilities, revenues
 
and expenses in joint operations in
accordance with the principles applicable to those particular assets, liabilities, revenues and expenses.
Those of Equinor's exploration and production licence activities that are within the scope
 
of IFRS 11 Joint Arrangements have been
classified as joint operations. A considerable number of Equinor's unincorporated joint exploration
 
and production activities are
conducted through arrangements that are not jointly controlled, either because unanimous consent is not
 
required among all parties
involved, or no single group of parties has joint control over the activity. Licence activities where control can be achieved through
agreement between more than one combination of involved parties are considered to be outside
 
the scope of IFRS 11, and these
activities are accounted for on a pro-rata basis using Equinor's ownership share. Currently, Equinor uses IFRS 11 by analogy for all
such unincorporated licence arrangements whether these are in scope of IFRS 11 or not. Reference is made to note 5 Segments for
financial information related to Equinor’s participation in joint operations within
 
upstream activities.
Joint ventures, in which Equinor has rights to the net assets, are accounted for using the equity method. These
 
currently include the
majority of Equinor’s investments in the Renewables (REN) operating and reporting
 
segment. Equinor’s participation in joint
arrangements that are joint ventures and investments in companies in which Equinor has neither
 
control nor joint control but has the
ability to exercise significant influence over operating and financial policies, are classified as
 
equity accounted investments.
Under the equity method, the investment is carried on the Consolidated balance sheet at cost
 
plus post-acquisition changes in
Equinor’s share of net assets of the entity, less distributions received and less any impairment in value of the investment. The part of
an equity accounted investment’s dividend distribution exceeding the entity’s carrying amount in the Consolidated balance
 
sheet is
reflected as income from equity accounted investments in the Consolidated statement of income. Equinor
 
will subsequently only
reflect the share of net profit in the investment that exceeds the dividend already reflected as income. The
 
Consolidated statement of
income reflects Equinor’s share of the results after tax of an equity accounted entity, adjusted to account for depreciation, amortisation
and any impairment of the equity accounted entity’s assets based on their fair values at the date of acquisition. Net
 
income/loss from
equity accounted investments is presented as part of Total revenues and other income, as investments in and participation with
significant influence in other companies engaged in energy-related business activities is considered to be
 
part of Equinor’s main
operating activities.
Acquisition of ownership shares in joint ventures and other equity accounted investments in which the
 
activity constitutes a business,
are accounted for in accordance with the requirements applicable to business combinations. Please
 
refer to note 6 Acquisitions and
disposals for more details on acquisitions.
Equinor as operator of joint operations and similar arrangements
Indirect operating expenses such as personnel expenses are accumulated in cost pools. These
 
costs are allocated on an hours’
incurred basis to business areas and Equinor-operated joint operations under IFRS 11 and to similar arrangements (licences) outside
the scope of IFRS 11. Costs allocated to the other partners' share of operated joint operations and similar arrangements are
reimbursed and only Equinor's share of the statement of income and balance sheet items related
 
to Equinor-operated joint operations
and similar arrangements are reflected in the Consolidated statement of income and the Consolidated
 
balance sheet.
-----------------------------------------------------------------------------------------------------------------------------
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
201
Joint ventures and other equity accounted investments
(in USD million)
2022
2021
Net investments at 1 January
2,686
2,270
Net income/(loss) from equity accounted investments
620
259
Impairment
1)
(832)
0
Acquisitions and increase in capital
337
475
Dividend and other distributions
(210)
(230)
Other comprehensive income/(loss)
384
(58)
Divestments, derecognition and decrease in paid in
 
capital
(22)
(31)
Other
(205)
1
Net investments at 31 December
2,758
2,686
1) Related to investments in Russia, see also note 6 Acquisitions and disposals.
Equity accounted investments consist of several investments, none above USD 0.6 billion. None
 
of the investments are significant on
an individual basis. Voting rights corresponds to ownership.
16 Financial investments and financial receivables
Non-current financial investments
At 31 December
(in USD million)
2022
2021
Bonds
1,448
1,822
Listed equity securities
794
1,131
Non-listed equity securities
491
393
Financial investments
2,733
3,346
Bonds and equity securities mainly relate to investment portfolios held by Equinor’s
 
captive insurance company and other listed and
non-listed equities held for long-term strategic purposes, mainly accounted for using fair value through
 
profit or loss.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
202
 
Equinor, Annual Report on Form 20-F 2022
 
Non-current prepayments and financial receivables
At 31 December
(in USD million)
2022
2021
Interest-bearing financial receivables
 
1,658
707
Other interest-bearing receivables
66
276
Prepayments and other non-interest-bearing receivables
339
104
Prepayments and financial receivables
2,063
1,087
Interest-bearing financial receivables consist primarily of receivables
 
from related parties, see note 27 Related parties. Other interest-
bearing receivables primarily relate to financial sublease and tax receivables.
Current financial investments
At 31 December
(in USD million)
2022
2021
Time deposits
12,373
7,060
Interest-bearing securities
17,504
14,186
Financial investments
29,876
21,246
At 31 December 2022, current financial investments
include USD 410 million in investment portfolios held by Equinor’s
 
captive
insurance company which mainly are accounted for using fair value through profit or loss.
 
The corresponding balance at 31 December
2021 was USD 300 million.
For information about financial instruments by category, see note 28
Financial instruments and fair value measurement
.
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
203
17 Inventories
Accounting policies
Inventories
Commodity inventories not held for trading purposes are stated at the lower of cost and net realisable
 
value. Cost is determined by the
first-in first-out method and comprises direct purchase costs, cost of production, transportation, and manufacturing
 
expenses. With
effect from 2022, due to the evolving trading business in the Group, fair value less cost to sell
 
(FVLCS) is considered the appropriate
measurement basis for commodity inventories held for trading purposes, with subsequent changes in FV
 
recognised in the
Consolidated statement of income under Other revenues. These inventories are categorised within level
 
2 of the fair value hierarchy.
Comparative numbers have not been restated due to materiality.
------------------------------------------------------------------------------------------------------------------------------
At 31 December
(in USD million)
2022
2021
Crude oil
2,115
2,014
Petroleum products
451
315
Natural gas
127
642
Commodity inventories at the lower of cost and net
 
realisable value
2,693
2,971
Natural gas held for trading purposes measured
 
at fair value
1,994
0
Other
517
424
Total inventories
5,205
3,395
The write-down of inventories from cost to net realisable value amounted to an expense
 
of USD 143 million and USD 77 million in
2022 and 2021, respectively. Inventories held for trading purposes consist of gas stores held by Danske Commodities.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
204
 
Equinor, Annual Report on Form 20-F 2022
 
18 Trade and other receivables
At 31 December
(in USD million)
2022
2021
Trade receivables from contracts with customers
1)
15,213
13,266
Other current receivables
992
1,436
Collateral receivables
2)
3,468
1,576
Receivables from participation in joint operations and
 
similar arrangements
661
491
Receivables from equity accounted associated companies
 
and other related parties
1,276
423
Total financial trade and other receivables
21,611
17,192
Non-financial trade and other receivables
841
736
Trade and other receivables
22,452
17,927
1) Trade receivables from contracts with customers are shown
 
net of an immaterial provision for expected
 
losses.
2) Mainly related to cash paid as security for
 
a portion of Equinor's credit exposure.
 
For more information about the credit quality of Equinor's counterparties, see note 4 Financial
 
risk and capital management. For
currency sensitivities, see note 28 Financial instruments and fair value measurement.
19 Cash and cash equivalents
Accounting policies
Cash and cash equivalents are accounted for at amortised cost and include cash in hand, current
 
balances with banks and similar
institutions, and short-term highly liquid investments that are readily convertible to known amounts
 
of cash, are subject to an
insignificant risk of changes in fair value and have a maturity of three months or less from the
 
acquisition date. Contractually
mandatory deposits in escrow bank accounts are included as restricted cash if the deposits are
 
provided as part of the Group’s
operating activities and therefore are deemed as held for the purpose of meeting short
‑
term cash commitments, and the deposits can
be released from the escrow account without undue expenses.
At 31 December
(in USD million)
2022
2021
Cash at bank available
2,220
2,673
Time deposits
836
1,906
Money market funds
3,106
2,714
Interest-bearing securities
3,276
4,740
Restricted cash, including collateral deposits
6,140
2,093
Cash and cash equivalents
15,579
14,126
Restricted cash at 31 December 2022 includes
 
collateral deposits of USD 6,128 million related to trading activities. Correspondingly,
collateral deposits at 31 December 2021 were USD 2,069 million. Collateral deposits are related
 
to certain requirements of exchanges
where Equinor is trading. The terms and conditions related to these requirements are
 
determined by the respective exchanges.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
205
20 Shareholders' equity and dividends
Number of
shares
NOK per value
NOK
USD
Share capital at 1 January 2022
3,257,687,707
 
2.50
 
8,144,219,267.50
 
1,163,987,792
 
Capital reduction
(82,217,548)
2.50
 
(205,543,870.00)
(21,951,527)
Share capital at 31 December 2022
3,175,470,159
 
2.50
 
7,938,675,397.50
 
1,142,036,265
 
Number of
shares
NOK per value
Common Stock
Authorised and issued
 
3,175,470,159
 
2.50
 
 
7,938,675,397.50
 
Treasury shares
Share buy-back programme
 
(42,619,172)
2.50
 
 
(106,547,930.00)
Employees share saving plan
 
(10,908,717)
2.50
 
 
(27,271,792.50)
Total outstanding shares
3,121,942,270
 
2.50
 
 
7,804,855,675.00
 
Equinor ASA has only one class of shares and all shares have voting rights. The holders
 
of shares are entitled to receive dividends as
and when declared and are entitled to one vote per share at the annual general
 
meeting of the company.
Dividend
During 2022, dividend for the third and for the fourth quarter of 2021 and dividend for
 
the first and second quarter of 2022 were
settled. Dividend declared but not yet settled is presented as dividends payable in the Consolidated
 
balance sheet. The Consolidated
statement of changes in equity shows declared dividend in the period (retained earnings). Dividend
 
declared in 2022 relates
 
to the
fourth quarter of 2021 and to the first three quarters of 2022.
On 7 February 2023, the board of directors proposed an ordinary cash dividend for the fourth
 
quarter of 2022 of USD 0.30 per share
and an extraordinary cash dividend of USD 0.60 per share (subject to annual general meeting
 
approval). The Equinor share will trade
ex-dividend 11 May 2023 on Oslo Børs and for ADR holders on New York Stock Exchange. Record date will be 12 May 2023 and
payment date will be 25 May 2023.
At 31 December
(in USD million)
2022
2021
Dividends declared
7,549
 
2,041
 
USD per share or ADS
2.4000
 
0.6300
 
Dividends paid
5,380
 
1,797
 
USD per share or ADS
1.6800
 
0.5600
 
NOK per share
16.4837
 
4.8078
 
-------------------------------------------------------------------------------------------------------------------------------------
Accounting policies
Share buy-back
Where Equinor has either acquired own shares under a share buy-back programme or
 
has placed an irrevocable order with a third
party for Equinor shares to be acquired in the market, such shares are reflected
 
as a reduction in equity as treasury shares. Treasury
shares are not included in the weighted average number of ordinary shares outstanding in the calculation
 
of Earnings per share. The
remaining outstanding part of an irrevocable order to acquire shares is accrued for and classified as Trade, other payables and
provisions.
-------------------------------------------------------------------------------------------------------------------------------------
Share buy-back programme
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
206
 
Equinor, Annual Report on Form 20-F 2022
 
The purpose of the share buy-back programme is to reduce the issued share capital
 
of the company. All shares repurchased as part
of the programme will be cancelled. According to an agreement between Equinor and the Norwegian
 
State, the Norwegian State will
participate in share buy-backs on a proportionate basis, ensuring that its ownership interest
 
in Equinor remains unchanged at 67%.
On 7 February 2023, the board proposed an annual share buy-back programme for 2023 with up to USD
 
6,000 million, including
shares to be redeemed from the Norwegian State, subject to authorisation from the annual general
 
meeting. The annual share buy-
back programme is expected to be executed when Brent Blend oil price is in or above the range
 
of 50-60 USD/bbl, Equinor’s net debt
to capital employed adjusted* stays within the communicated ambition of 15-30 % and this is supported
 
by commodity prices.
On 7 February 2023, the board of directors resolved the commencement of the first tranche
 
of the share buy-back programme for
2023 of a total of USD 1,000 million, including shares to be redeemed from the Norwegian State.
 
The first tranche will end no later
than 24 March 2023.
Number of shares
2022
2021
Share buy-back programme at 1 January
 
13,460,292
 
 
-
 
Purchase
 
56,290,671
 
 
13,460,292
 
Cancellation
 
(27,131,791)
 
-
 
Share buy-back programme at 31 December
 
42,619,172
 
 
13,460,292
 
Equity impact of share buy back programmes
(in USD million)
2022
2021
First tranche
 
330
 
 
99
 
Second tranche
 
440
 
 
330
 
Third tranche
 
605
 
 
-
 
Fourth tranche
 
605
 
 
-
 
Norwegian state share
1)
 
1,399
 
 
-
 
Total
 
3,380
 
 
429
 
1) Relates to the 2021 programme and first tranche of 2022 programme.
In February 2022, Equinor launched a share buy-back programme for 2022 of up to USD 5,000 million, where
 
the first tranche of
around USD 1,000 million was finalised in March 2022. USD 330 million of the first
 
tranche was acquired in the open market. The
redemption of the proportionate share of 67% from the Norwegian State was approved by the annual
 
general meeting 11 May 2022
and settled in July 2022 as described below.
In May 2022, Equinor launched the second tranche of USD 1,333 million of the 2022
 
share buy-back programme of which USD 440
million was purchased in the open market. The acquisition of the second tranche in the
 
open market was finalised in July 2022.
In July 2022, Equinor increased the target level of share buy-back for 2022 from USD 5,000
 
million up to USD 6,000 million and
launched the third tranche of USD 1,833 million. USD 605 million was purchased in
 
the open market. The acquisition of the third
tranche in the open market was finalised in October 2022.
In October 2022, Equinor launched the fourth and final tranche of the share buy-back programme
 
for 2022 of USD 1,833 million. The
fourth tranche of USD 605 million (both acquired and remaining order) has been recognised as a reduction
 
in equity as treasury
shares due to an irrevocable agreement with a third party. As of 31 December 2022, USD 495
million of the fourth tranche has been
purchased in the open market, of which USD 475 million has been settled. The remaining order
 
of the fourth tranche is accrued for
and classified as Trade, other payables and provisions. The acquisition of the fourth tranche in the open market was finalised
 
in
January 2023.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
207
After having finalised the 2021 share buy-back programme as well as the first tranche
 
of the 2022 share buy-back programme in the
market in the period 28 July 2021 to 25 March 2022, a proportionate share of 67% from the
 
Norwegian State was redeemed in
accordance with an agreement with the Ministry of Trade, Industry and Fisheries for the Norwegian State to maintain
 
their ownership
percentage in Equinor. The redemption was approved by the annual general meeting held on 11 May 2022. The shares were
cancelled on 29 June 2022 and the liability of USD 1,399 million (NOK 13,496 million) to the
 
Norwegian State was settled on 20 July
2022.
For the second, third and fourth tranche of the share buy-back programme of 2022, USD 3,350 million of shares
 
from the Norwegian
State will, in accordance with an agreement with the Ministry of Trade, Industry and Fisheries, be redeemed at the annual
 
general
meeting in May 2023 in order for the Norwegian State to maintain its ownership share
 
of 67% in Equinor.
Employees share saving plan
Number of shares
2022
2021
Share saving plan at 1 January
 
12,111,104
 
 
11,442,491
 
Purchase
 
2,127,172
 
 
3,412,994
 
Allocated to employees
 
(3,329,559)
 
(2,744,381)
Share saving plan at 31 December
 
10,908,717
 
 
12,111,104
 
In 2022 and 2021 treasury shares were purchased and allocated to employees participating in the share
 
saving plan for USD 72
million and USD 75 million, respectively. For further information, see note 8 Salaries and personnel expenses.
21 Finance debt
Non-current finance debt
Finance debt measured at amortised cost
Weighted average interest
rates in %
1)
Carrying amount in USD
millions at 31 December
Fair value in USD
 
millions at 31 December
2)
2022
2021
2022
2021
2022
2021
Unsecured bonds
United States Dollar (USD)
3.82
3.88
17,190
17,451
16,167
19,655
Euro (EUR)
1.42
1.42
7,465
7,925
6,782
8,529
Great Britain Pound (GBP)
6.08
6.08
1,652
1,852
1,836
2,674
Norwegian Kroner (NOK)
4.18
4.18
304
340
311
380
Total unsecured bonds
26,612
27,568
25,097
31,237
Unsecured loans
Japanese Yen (JPY)
4.30
4.30
76
87
90
106
Total unsecured loans
76
87
90
106
Total
26,688
27,655
25,187
31,343
Non-current finance debt due within one year
2,547
250
2,597
268
Non-current finance debt
24,141
27,404
22,590
31,075
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
208
 
Equinor, Annual Report on Form 20-F 2022
 
1)
 
Weighted average interest rates are calculated based on the contractual rates on the loans per currency at 31 December
 
and do
not include the effect of swap agreements.
2)
 
Fair values are determined from external calculation models based on market observations
 
from various sources, classified at
level 2 in the fair value hierarchy. For more information regarding fair value hierarchy, see note 28 Financial instruments and fair
value measurement.
Unsecured bonds amounting to USD 17,190 million are denominated in USD and unsecured bonds denominated
 
in other currencies
amounting to USD 8,624 million are swapped into USD. One bond denominated in EUR amounting
 
to USD 797 million is not
swapped. The table does not include the effects of agreements entered into to swap the various currencies into
 
USD. For further
information see note 28 Financial instruments and fair value measurement.
Substantially all unsecured bonds and unsecured bank loan agreements contain provisions restricting future
 
pledging of assets to
secure borrowings without granting a similar secured status to the existing bondholders and lenders.
No new bonds were issued in 2022.
Out of Equinor's total outstanding unsecured bond portfolio, 38 bond agreements contain provisions
 
allowing Equinor to call the debt
prior to its final redemption at par or at certain specified premiums if there are changes to
 
the Norwegian tax laws. The carrying
amount of these agreements is USD 26,302 million at the 31 December 2022 closing currency exchange
 
rate.
For more information about the revolving credit facility, maturity profile for undiscounted cash flows and interest rate risk management,
see note 4 Financial risk and capital management.
 
Non-current finance debt maturity profile
At 31 December
(in USD million)
2022
2021
Year 2 and 3
4,794
5,015
Year 4 and 5
4,510
4,731
After 5 years
14,837
17,659
Total repayment of non-current finance debt
24,141
27,404
Weighted average maturity (years - including current portion)
9
10
Weighted average annual interest rate (% - including current portion)
3.29
3.33
Current finance debt
At 31 December
(in USD million)
2022
2021
Collateral liabilities
1,571
2,271
Non-current finance debt due within one year
2,547
250
Other including US Commercial paper programme
 
and bank overdraft
241
2,752
Total current finance debt
4,359
5,273
Weighted average interest rate (%)
2.22
0.51
Collateral liabilities and other current liabilities mainly relate to cash received as security for
 
a portion of Equinor's credit exposure and
outstanding amounts on US Commercial paper (CP) programme. Issuance on the CP programme
 
amounted to USD 227 million as of
 
31 December 2022 and USD 2,600 million as of 31 December 2021.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
209
Reconciliation of cash flows from financing activities
 
to finance line items in balance sheet
 
(in USD million)
Non-current
finance debt
Current
finance
debt
Financial
receivable
Collaterals
1)
Additional
paid in
capital
 
/Treasury
shares
Non-
controlling
interest
Dividend
payable
Lease
liabilities
2)
Total
At 1 January 2022
27,404
5,273
(1,577)
(2,027)
14
582
3,562
New finance debt
-
Repayment of finance debt
(250)
(250)
Repayment of lease liabilities
(1,366)
(1,366)
Dividend paid
(5,380)
(5,380)
Share buy-back
(3,315)
(3,315)
Net current finance debt and other
finance activities
(2,982)
(2,038)
(73)
(8)
(5,102)
Net cash flow from financing activities
(250)
(2,982)
(2,038)
(3,388)
(8)
(5,380)
(1,366)
(15,414)
Transfer to current portion
(2,297)
2,297
Effect of exchange rate changes
(710)
(78)
145
(3)
(149)
Dividend declared
7,549
New leases
1,644
Other changes
(7)
(151)
30
(2)
57
(24)
Net other changes
(3,014)
2,068
145
30
(5)
7,606
1,471
At 31 December 2022
24,141
4,359
(3,468)
(5,385)
1
2,808
3,667
(in USD million)
Non-current
finance debt
Current
finance
debt
Financial
receivable
Collaterals
1)
Additional
paid in
capital
 
/Treasury
shares
Non-
controlling
interest
Dividend
payable
Lease
liabilities
2)
Total
At 1 January 2021
29,118
4,591
(967)
(1,588)
19
357
4,406
New finance debt
-
Repayment of finance debt
(2,675)
(2,675)
Repayment of lease liabilities
(1,238)
(1,238)
Dividend paid
(1,797)
(1,797)
Share buy-back
(321)
(321)
Net current finance debt and other
finance activities
(335)
2,273
(651)
(75)
(18)
1,195
Net cash flow from financing activities
(3,010)
2,273
(651)
(396)
(18)
(1,797)
(1,238)
(4,836)
Transfer to current portion
1,724
(1,724)
Effect of exchange rate changes
(422)
(8)
41
(1)
(61)
Dividend declared
2,041
New leases
476
Other changes
(6)
141
-
(43)
14
(19)
(21)
Net other changes
1,296
(1,591)
41
(43)
13
2,022
394
At 31 December 2021
27,404
5,273
(1,577)
(2,027)
14
582
3,562
210
 
Equinor, Annual Report on Form 20-F 2022
 
1)
 
Financial receivable collaterals are included in Trade and other receivables in the Consolidated balance sheet. See note 18
Trade and other receivables for more information.
2)
 
See note 25 Leases for more information.
Equinor, Annual Report on Form 20-F 2022
 
211
22 Pensions
Accounting policies
Equinor has pension plans for employees that either provide a defined pension benefit upon retirement or a pension
 
dependent on
defined contributions and related returns. A portion of the contributions are provided
 
for as notional contributions, for which the liability
increases with a promised notional return, set equal to the actual return of assets invested through
 
the ordinary defined contribution
plan. For defined benefit plans, the benefit to be received by employees generally
 
depends on many factors including length of
service, retirement date and future salary levels.
Equinor's proportionate share of multi-employer defined benefit plans is recognised as liabilities in the Consolidated
 
balance sheet as
sufficient information is considered available, and a reliable estimate of the obligation can be made.
The cost of pension benefit plans is expensed over the period that the employees render services
 
and become eligible to receive
benefits. The calculation is performed by an external actuary. Equinor's net obligation from defined benefit pension plans is calculated
separately for each plan by estimating the amount of future benefit that employees have earned in
 
return for their services in the
current and prior periods. That benefit is discounted to determine its present value, and the fair
 
value of any plan assets is deducted.
The discount rate is the yield at the balance sheet date, reflecting the maturity dates approximating
 
the terms of Equinor's obligations.
On 31 December 2022, the discount rate for the defined benefit plans in Norway was established
 
on the basis of seven years'
mortgage covered bonds interest rate extrapolated on a yield curve which matches the duration of Equinor's
 
payment portfolio for
earned benefits, which was calculated to be 13.5 years at the end of 2022. The present
 
values of the defined benefit obligation, the
related current service cost and past service cost are measured using the projected unit credit method.
 
The assumptions for expected
wage growth, expected rate of pension increase and the expected increase of social security base
 
amount (G-amount) are based on
agreed regulation in the plans, historical observations, future expectations of the assumptions and the
 
relationship between these
assumptions. For members in Norway, the mortality table K2013, issued by The Financial Supervisory Authority of Norway, is used as
the best mortality estimate. Social security tax is calculated based on a pension plan's net funded status and
 
is included in the defined
benefit obligation.
The recognition of a net surplus for the funded plan is based on the assumption that the net assets
 
represent a future value for
Equinor, either as a possible distribution to premium fund which can be used for future funding of new liabilities, or as disbursement of
equity in the pension fund.
The net interest related to defined benefit plans is calculated by applying the discount rate to
 
the net present value of the benefit
obligation and is presented in the Consolidated statement of income within Net financial items.
 
The difference between estimated
interest income and actual return is recognised in the Consolidated statement of comprehensive
 
income as actuarial gains/losses.
Actuarial gains and losses are recognised in full in the Consolidated statement of comprehensive
 
income in the period in which they
occur, while actuarial gains and losses related to provision for termination benefits are recognised in the Consolidated statement of
income in the period in which they occur. Due to the parent company Equinor ASA's functional currency being USD, the
 
significant
part of Equinor's pension obligations will be payable in a foreign currency (i.e. NOK). As
 
a consequence, actuarial gains and losses
related to the parent company's pension obligations include the impact of exchange rate fluctuations.
Contributions to defined contribution schemes are recognised in the Consolidated statement of income
 
as pension costs in the period
in which the contribution amounts are earned by the employees.
Notional contribution plans, reported in the parent company Equinor ASA, are recognised as Pension
 
liabilities with the actual value of
the notional contributions and promised return at reporting date. Notional contributions are recognised
 
in the Consolidated statement
of income as periodic pension cost, while changes in fair value of the employees’ notional assets
 
are reflected in the Consolidated
statement of income under Net financial items.
Periodic pension cost is accumulated in cost pools and allocated to business areas and Equinor’s
 
operated joint operations (licences)
on an hours’ incurred basis and recognised in the Consolidated statement of income based on
 
the function of the cost.
------------------------------------------------------------------------------------------------------------------------------------
Pension plans in Equinor
The main pension plans for Equinor ASA and its most significant subsidiaries are defined contribution plans which
 
includes certain
unfunded elements (notional contribution plans). In addition, several employees and former employees of
 
the Equinor Group is a
member of certain defined benefit plans. The benefit plan in Equinor ASA was closed in 2015
 
for new employees and for employees
with more than 15 years to regular retirement age. Equinor's defined benefit plans are generally
 
based on a minimum of 30 years of
service and 66% of the final salary level, including an assumed benefit from the Norwegian National
 
Insurance Scheme. The
 
 
 
 
 
 
 
 
 
212
 
Equinor, Annual Report on Form 20-F 2022
 
Norwegian companies in the group are subject to, and complies with, the requirements of the Norwegian
 
Mandatory Company
Pensions Act.
The defined benefit plans in Norway are managed and financed through Equinor Pensjon (Equinor's
 
pension fund - hereafter Equinor
Pension). Equinor Pension is an independent pension fund that covers the employees in Equinor's
 
Norwegian companies. The
pension fund's assets are kept separate from the company's and group companies' assets. Equinor Pension
 
is supervised by the
Financial Supervisory Authority of Norway ("Finanstilsynet") and is licenced to operate as a pension
 
fund.
Equinor has more than one defined benefit plan, but the disclosure is made in total since
 
the plans are not subject to materially
different risks. Pension plans outside Norway are not material and as such not disclosed separately. The tables in this note present
pension costs on a gross basis before allocation to licence partners. In the Consolidated statement
 
of income, the pension costs in
Equinor ASA are presented net of costs allocated to licence partners.
Equinor is also a member of a Norwegian national agreement-based early retirement plan (“AFP”),
 
and the premium is calculated
based on the employees' income but limited to 7.1 times the basic amount in the National Insurance
 
scheme (7.1 G). The premium is
payable for all employees until age 62. Pension from the AFP scheme will be paid from
 
the AFP plan administrator to employees for
their full lifetime.
Net pension cost
(in USD million)
2022
2021
2020
Notional contribution plans
57
60
55
Defined benefit plans
188
216
184
Defined contribution plans
213
213
192
Total net pension cost
458
488
432
In addition to the pension cost presented in the table above, financial items related to
 
defined benefit plans are included in the
Consolidated statement of income within Net financial items. Interest cost and changes in fair value of
 
notional contribution plans
amounts to USD 105 million in 2022 and USD 238 million in 2021. Interest income of USD
 
116 million has been recognised in 2022,
and USD 106 million in 2021.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
213
Changes in pension liabilities and plan assets
 
during the year
(in USD million)
2022
2021
Pension liabilities at 1 January
9,358
9,216
Current service cost
183
208
Interest cost
105
238
Actuarial (gains)/losses and currency effects
(1,785)
(72)
Changes in notional contribution liability and other
 
effects
67
63
Benefits paid
(258)
(295)
Pension liabilities at 31 December
7,670
9,358
Fair value of plan assets at 1 January
6,404
6,234
Interest income
116
106
Return on plan assets (excluding interest income)
(622)
291
Company contributions
104
114
Benefits paid
(121)
(137)
Other effects
6
-
Foreign currency translation effects
(669)
(204)
Fair value of plan assets at 31 December
5,218
6,404
Net pension liability at 31 December
2,452
2,954
Represented by:
Asset recognised as non-current pension assets
 
(funded plan)
1,219
1,449
Liability recognised as non-current pension liabilities
 
(unfunded plans)
3,671
4,403
Pension liabilities specified by funded and unfunded
 
pension plans
7,670
9,358
Funded
3,999
4,955
Unfunded
3,671
4,403
Equinor recognised an actuarial gain from changes in financial assumptions in 2022, mainly due to a larger
 
increase in discount rate
compared to the other assumptions. An actuarial loss was recognised in 2021.
Actuarial losses and gains recognised directly
 
in Other comprehensive income (OCI)
(in USD million)
2022
2021
2020
Net actuarial (losses)/gains recognised in OCI
 
during the year
174
63
3
Foreign currency translation effects
287
84
(109)
Tax effects of actuarial (losses)/gains recognised in OCI
(105)
(35)
19
Recognised directly in OCI during the year, net of tax
356
112
(87)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
214
 
Equinor, Annual Report on Form 20-F 2022
 
Actuarial assumptions
Assumptions used to determine
benefit costs in %
Assumptions used to determine
benefit obligations in %
Rounded to the nearest quartile
2022
2021
2022
2021
Discount rate
2.00
1.75
3.75
2.00
Rate of compensation increase
2.50
2.00
3.50
2.50
Expected rate of pension increase
1.75
1.25
2.75
1.75
Expected increase of social security base amount (G-amount)
2.25
2.00
3.25
2.25
Weighted-average duration of the defined benefit obligation
13.5
15.2
The assumptions presented are for the Norwegian companies in Equinor which are members of
 
Equinor's pension fund. The defined
benefit plans of other subsidiaries are immaterial to the consolidated pension assets and liabilities.
Sensitivity analysis
The table below presents an estimate of the potential effects of changes in the key assumptions for the defined benefit
 
plans. The
following estimates are based on facts and circumstances as of 31 December 2022.
Discount rate
Expected rate of
compensation
increase
Expected rate of
pension increase
Mortality assumption
(in USD million)
0.50%
-0.50%
0.50%
-0.50%
0.50%
-0.50%
+ 1 year
- 1 year
Effect on:
Defined benefit obligation at 31 December 2022
(491)
553
109
(104)
462
(422)
285
(257)
Service cost 2023
(16)
18
8
(7)
12
(11)
6
(5)
The sensitivity of the financial results to each of the key assumptions has been estimated
 
based on the assumption that all other
factors would remain unchanged. The estimated effects on the financial result would differ from those that would
 
actually appear in the
Consolidated financial statements because the Consolidated financial statements would also reflect the
 
relationship between these
assumptions.
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
215
Pension assets
The plan assets related to the defined benefit plans were measured at fair value. Equinor Pension
 
invests in both financial assets and
real estate.
The table below presents the portfolio weighting as approved by the board of Equinor Pension
 
for 2022. The portfolio weight during a
year will depend on the risk capacity.
Target portfolio
weight
(in %)
2022
2021
Equity securities
32.9
34.1
 
29-38
Bonds
53.1
50.2
 
46-59
Money market instruments
7.4
9.1
 
0-14
Real estate
6.6
6.6
 
5-10
Total
100.0
100.0
In 2022, 44% of the equity securities and 3% of bonds had quoted market prices in an active market.
 
54% of the equity securities,
97% of bonds and 100% of money market instruments had market prices based on inputs other
 
than quoted prices. If quoted market
prices are not available, fair values are determined from external calculation models based on market
 
observations from various
sources.
In 2021, 61% of the equity securities and 3% of bonds had quoted market prices in an active market.
 
37% of the equity securities,
97% of bonds and 100% of money market instruments had market prices based on inputs other
 
than quoted prices.
For definition of the various levels, see note 28 Financial instruments and fair value measurement.
Estimated company contributions to be made to Equinor Pension in 2023 is approximately USD
 
108 million.
23 Provisions and other liabilities
Accounting policies
Asset retirement obligations (ARO)
Provisions for asset retirement obligations (ARO) are recognised when Equinor has an obligation
 
(legal or constructive) to dismantle
and remove a facility or an item of property, plant and equipment and to restore the site on which it is located, and when a reliable
estimate of that liability can be made. Normally an obligation arises for a new facility, such as an oil and natural gas production or
transportation facility, upon construction or installation. An obligation may also arise during the period of operation of a facility through
a change in legislation or through a decision to terminate operations or be based on commitments
 
associated with Equinor's ongoing
use of pipeline transport systems where removal obligations rest with the volume shippers.
The amount recognised is the present value of the estimated future expenditures determined in accordance with
 
local conditions and
requirements. The cost is estimated based on current regulations and technology, considering relevant risks and uncertainties. The
discount rate used in the calculation of the ARO is a market-based risk-free rate based on the
 
applicable currency and time horizon of
the underlying cash flows. The provisions are classified under Provisions in the Consolidated
 
balance sheet.
When a provision for ARO is recognised, a corresponding amount is recognised to increase the
 
related property, plant and equipment
and is subsequently depreciated as part of the property, plant and equipment. Any change in the present value of the estimated
expenditure is reflected as an adjustment to the provision and the corresponding property, plant and equipment. When a decrease in
the ARO related to a producing asset exceeds the carrying amount of the asset, the excess is
 
recognised as a reduction of
Depreciation, amortisation and net impairment losses in the Consolidated statement of income.
 
When an asset has reached the end
of its useful life, all subsequent changes to the ARO are recognised as they occur
 
in Operating expenses in the Consolidated
statement of income.
Removal provisions associated with Equinor's role as shipper of volumes through third party transport
 
systems are expensed as
incurred.
Estimation uncertainty regarding asset retirement obligations
Establishing the appropriate estimates for such obligations are based on historical knowledge combined with
 
knowledge of ongoing
technological developments, expectations about future regulatory and technological development and involve
 
the application of
 
 
 
 
 
 
 
 
 
 
 
 
216
 
Equinor, Annual Report on Form 20-F 2022
 
judgement and an inherent risk of significant adjustments. The costs of decommissioning and
 
removal activities require revisions due
to changes in current regulations and technology while considering relevant risks and uncertainties.
 
Most of the removal activities are
many years into the future, and the removal technology and costs are constantly changing. The
 
speed of the transition to renewable
energy sources may also influence the production period, hence the timing of the removal activities.
 
The estimates include
assumptions of norms, rates and time required which can vary considerably depending on the
 
assumed removal complexity.
Moreover, changes in the discount rate and foreign currency exchange rates may impact the estimates significantly. As a result, the
initial recognition of ARO and subsequent adjustments involve the application of significant
 
judgement.
---------------------------------------------------------------------------------------------------------------------------------
(in USD million)
Asset retirement
obligations
Other
 
provisions and
liabilities,
including
claims and
litigations
Total
Non-current portion at 31 December 2021
17,279
2,620
19,899
Current portion at 31 December 2021 reported
 
as Trade, other payables and
provisions
138
1,566
1,704
Provisions and other liabilities at 31 December 2021
17,417
4,186
21,603
New or increased provisions and other liabilities
998
497
1,495
Change in estimates
(255)
1,283
1,028
Amounts charged against provisions and other liabilities
(204)
(1,830)
(2,034)
Effects of change in the discount rate
(4,920)
(212)
(5,132)
Reduction due to divestments
(361)
(181)
(542)
Accretion expenses
387
62
449
Reclassification and transfer
(46)
841
795
Foreign currency translation effects
(1,282)
(88)
(1,370)
Provisions and other liabilities at 31 December 2022
11,734
4,558
16,292
Non-current portion at 31 December 2022
11,569
4,064
15,633
Current portion at 31 December 2022 reported
 
as Trade, other payables and
provisions
165
494
659
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
217
Equinor's estimated asset retirement obligations (ARO) have decreased by USD 5,683 million to USD
 
11,734 million at 31 December
2022 compared to year-end 2021, mainly due to increased discount rates and strengthening
 
of USD versus NOK. Changes in ARO
are reflected within Property, plant and equipment and Provisions and other liabilities in the Consolidated balance sheet.
In certain production sharing agreements (PSA), Equinor’s estimated share of asset retirement
 
obligation (ARO) is paid into an escrow
account over the producing life of the field. These payments are considered down-payments of the
 
liabilities and included in the line
item Amounts charged against provisions and other liabilities.
Claims and litigations mainly relate to expected payments for unresolved claims. The timing
 
and amounts of potential settlements in
respect of these claims are uncertain and dependent on various factors that are outside management's
 
control. For further information
on provisions and contingent liabilities, see note 26 Other commitments, contingent liabilities and
 
contingent assets.
 
The timing of cash outflows of asset retirement obligations depends on the expected cease of production
 
at the various facilities.
Line item Change in estimates includes USD 791 million related to SDFI liability. See note 27 Related parties for further details.
Line item Amounts charged against provisions and other liabilities includes settlement of USD 1,050
 
million related to Brazilian
Offshore licence BM-S-8.
Sensitivities with regards to discount rate on the total ARO portfolio
The discount rate sensitivity has been calculated by assuming a reasonably possible change of 1.2 percentage
 
points.
An increase in the discount rate of 1.2 percentage points would reduce the ARO liability by USD
 
1,705 million. A corresponding
reduction would increase the liability by USD 2,190 million. See note 3 Consequences
 
of initiatives to limit climate changes for
sensitivity with regards to change in the removal year.
Expected timing of cash outflows
(in USD million)
Asset retirement
obligations
Other
 
provisions and
liabilities, including
claims and litigations
Total
2023 - 2027
1,201
3,664
4,865
2028 - 2032
1,239
198
1,437
2033 - 2037
4,058
158
4,216
2038 - 2042
3,429
24
3,453
Thereafter
1,807
514
2,321
At 31 December 2022
11,734
4,558
16,292
24 Trade, other payables and provisions
At 31 December
(in USD million)
2022
2021
Trade payables
6,207
6,249
Non-trade payables and accrued expenses
2,688
2,181
Payables due to participation in joint operations and
 
similar arrangements
2,074
1,876
Payables to equity accounted associated companies
 
and other related parties
1,479
2,045
Total financial trade and other payables
12,449
12,350
Current portion of provisions and other non-financial
 
payables
903
1,960
Trade, other payables and provisions
13,352
14,310
Included in Current portion of provisions and other non-financial payables are certain provisions that
 
are further described in note 23
Provisions and other liabilities and in note 26 Other commitments, contingent liabilities and contingent
 
assets. For information
 
 
 
 
 
 
 
218
 
Equinor, Annual Report on Form 20-F 2022
 
regarding currency sensitivities, see note 28 Financial instruments and fair value measurement. For further
 
information on payables to
equity accounted associated companies and other related parties, see note 27 Related parties.
25 Leases
Accounting policies
Leases
A lease is defined as a contract that conveys the right to control the use of an identified asset for
 
a period of time in exchange for
consideration. At the date at which the underlying asset is made available for Equinor, the present value of future lease
 
payments
(including extension options considered reasonably certain to be exercised) is recognised as a lease liability. The present value is
calculated using Equinor’s incremental borrowing rate. A corresponding right-of-use
 
(RoU) asset is recognised, including lease
payments and direct costs incurred at the commencement date. Lease payments are reflected as interest
 
expense and a reduction of
lease liabilities. The RoU assets are depreciated over the shorter of each contract’s term and the
 
assets’ useful life.
Short term leases (12 months or less) and leases of low value assets (regarded as such when
 
the sum of nominal lease payments
over the lease term do not exceed USD 500.000) are expensed or (if appropriate) capitalised as
 
incurred, depending on the activity in
which the leased asset is used.
Many of Equinor’s lease contracts, such as rig and vessel leases, involve several additional
 
services and components, including
personnel cost, maintenance, drilling related activities, and other items. For a number of these
 
contracts, the additional services
represent a not inconsiderable portion of the total contract value. Non-lease components within lease contracts
 
are accounted for
separately for all underlying classes of assets and reflected in the relevant expense category or (if
 
appropriate) capitalised as
incurred, depending on the activity involved.
Accounting judgement regarding leases
In the oil and gas industry, where activity frequently is carried out through joint arrangements or similar arrangements, the application
of IFRS 16 Leases requires evaluations of whether the joint arrangement or its operator is the
 
lessee in each lease agreement and
consequently whether such contracts should be reflected gross (100%) in the operator’s
 
financial statements, or according to each
joint operation partner’s proportionate share of the lease.
In many cases where an operator is the sole signatory to a lease contract of an asset to
 
be used in the activities of a specific joint
operation, the operator does so implicitly or explicitly on behalf of the joint arrangement. In certain jurisdictions,
 
and importantly for
Equinor as this includes the Norwegian continental shelf (NCS), the concessions granted by the
 
authorities establish both a right and
an obligation for the operator to enter into necessary agreements in the name of the joint operations
 
(licences).
As is the customary norm in upstream activities operated through joint arrangements, the operator
 
will manage the lease, pay the
lessor, and subsequently re-bill the partners for their share of the lease costs. In each such instance, it is necessary to determine
whether the operator is the sole lessee in the external lease arrangement, and if
 
so, whether the billings to partners may represent
sub-leases, or whether it is in fact the joint arrangement which is the lessee, with each
 
participant accounting for its proportionate
share of the lease. Where all partners in a licence are considered to share the primary responsibility for lease
 
payments under a
contract, Equinor’s proportionate share of the related lease liability and RoU asset will
 
be recognised net by Equinor. When Equinor is
considered to have the primary responsibility for the full external lease payments, the lease liability is recognised
 
gross (100%).
Equinor derecognises a portion of the RoU asset equal to the non-operator’s
 
interests in the lease, and replace it with a corresponding
financial lease receivable, if a financial sublease is considered to exist between Equinor and the licence.
 
A financial sublease will
typically exist where Equinor enters into a contract in its own name, has the primary responsibility for
 
the external lease payments, the
underlying asset will only be used on one specific licence, and the costs and risks related to the
 
use of the asset are carried by that
specific licence. Depending on facts and circumstances in each case, the conclusions reached
 
may vary between contracts and legal
jurisdictions.
--------------------------------------------------------------------------------------------------------------------------------
Equinor leases certain assets, notably drilling rigs, transportation vessels, storages and office facilities for operational activities.
Equinor is mostly a lessee, and the use of leases serves operational purposes rather than
 
as a tool for financing.
Information related to lease payments and lease liabilities
(in USD million)
2022
2021
Lease liabilities at 1 January
3,562
4,406
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
219
New leases, including remeasurements and cancellations
1,644
476
Gross lease payments
(1,484)
(1,350)
Lease interest
95
91
Lease repayments
 
(1,389)
(1,389)
(1,259)
(1,259)
Foreign currency translation effects
(149)
(61)
Lease liabilities at 31 December
3,667
3,562
Current lease liabilities
1,258
1,113
Non-current lease liabilities
2,409
2,449
Lease expenses not included in lease liabilities
(in USD million)
2022
2021
Short-term lease expenses
286
160
Payments related to short term leases are mainly related to drilling rigs and transportation
 
vessels, for which a significant portion of
the lease costs have been included in the cost of other assets, such as rigs used
 
in exploration or development activities. Variable
lease expense and lease expense related to leases of low value assets are not significant.
Equinor recognised revenues of USD 319 million in 2022 and USD 272 million in 2021 related to lease
 
costs recovered from licence
partners related to lease contracts being recognised gross by Equinor.
Commitments relating to lease contracts which had not yet commenced at year-end are included
 
within Other commitments in note
 
26 Other commitments, contingent liabilities and contingent assets.
A maturity profile based on undiscounted contractual cash flows for lease liabilities is
 
disclosed in note 4 Financial risk and capital
management.
Non-current lease liabilities maturity profile
At 31 December
(in USD million)
2022
2021
Year 2 and 3
1,360
1,164
Year 4 and 5
483
586
After 5 years
566
699
Total repayment of non-current lease liabilities
2,409
2,449
The Right of use assets are included within the line item Property, plant and equipment in the Consolidated balance sheet. See also
note 12 Property, plant and equipment.
 
 
 
 
 
 
 
220
 
Equinor, Annual Report on Form 20-F 2022
 
26 Other commitments, contingent liabilities and contingent
 
assets
Accounting policies
Estimation uncertainty regarding levies
Equinor’s global business activities are subject to different indirect taxes in various jurisdictions around the world. In these
jurisdictions, governments can respond to global or local development, including climate related matters and public fiscal
balances, by issuing new laws or other regulations stipulating changes in value added tax, tax on emissions, customs duties or
other levies which may affect profitability and even the viability of Equinor’s business in that jurisdiction. Equinor mitigates this
risk by using local legal representatives and staying up to date with the legislation in the jurisdictions where activities are
carried out. Occasionally, legal disputes arise from difference in interpretations. Equinor’s legal department, together with local
legal representatives, estimate the outcome from such legal disputes based on first-hand knowledge. Such estimates may
differ from the actual results.
--------------------------------------------------------------------------------------------------------------------------------
Contractual commitments
Equinor had contractual commitments of USD 5,454 million as of 31 December 2022. The
 
contractual commitments reflect Equinor's
proportional share and mainly comprise construction and acquisition of property, plant and equipment as well as committed
investments/funding or resources in equity accounted entities. It also includes Equinors’ estimated
 
expenditures related to
commitments to drill a certain number of wells, commitments which sometimes can be a prerequisite to be awarded
 
oil and gas
exploration and production licences.
At the end of 2022, Equinor was committed to participate in 40 wells, with an average
 
ownership interest of approximately 42%.
Equinor's share of estimated expenditures to drill these wells amounts to USD 566 million. Additional
 
wells that Equinor may become
committed to participating in depending on future discoveries in certain licences are not included in
 
these numbers.
Other long-term commitments
Equinor has entered into various long-term agreements for pipeline transportation as well as terminal
 
use, processing, storage and
entry/exit capacity commitments and commitments related to specific purchase agreements. The
 
agreements ensure the rights to the
capacity or volumes in question, but also impose on Equinor the obligation to pay for the agreed-upon
 
service or commodity,
irrespective of actual use. The contracts' terms vary, with durations of up to 2060.
Take-or-pay contracts for the purchase of commodity quantities are only included in the table below if their contractually agreed
pricing is of a nature that will or may deviate from the obtainable market prices for the
 
commodity at the time of delivery.
Obligations payable by Equinor to entities accounted for in the Equinor group using the equity method
 
are included in the table below
with Equinor’s full proportionate share. For assets (such as pipelines) that are included in
 
the Equinor accounts through joint
operations or similar arrangements, and where consequently Equinor’s share of
 
assets, liabilities, income and expenses (capacity
costs) are reflected on a line-by-line basis in the Consolidated financial statements, the amounts in the table include
 
the net
commitment payable by Equinor (i.e. Equinor’s proportionate share of the
 
commitment less Equinor's ownership share in the
applicable entity).
The table below also includes USD 3,033 million as the non-lease components of lease agreements
 
reflected in the accounts
according to IFRS 16, as well as leases not yet commenced. For commenced leases, please refer to
 
note 25 Leases.
Nominal minimum other long-term commitments at 31 December 2022:
(in USD million)
2023
2,603
2024
2,103
2025
1,892
2026
1,260
2027
1,309
Thereafter
5,733
Total other long-term commitments
14,900
Equinor, Annual Report on Form 20-F 2022
 
221
Guarantees
Equinor has guaranteed for its proportionate share of some of our associates’
 
long-term bank debt, payment obligations under
contracts, and certain third-party obligations. The total amount guaranteed at year-end 2022 is USD
 
1,725 million. The book value of
the guarantees is immaterial.
Contingent liabilities and contingent assets
Agbami dispute settlement agreement and licence extension
During 2022, an agreement was reached in a three-year long negotiation between the parties
 
Nigerian National Petroleum Company
Limited (NNPC), Chevron and Equinor. The parties have agreed to an extension of the operating licence period and the related
Production Sharing Contract (PSC) for Oil Mining Lease (OML) 128 of the unitised Agbami field
 
until 2042. At the same time, the
parties agreed outstanding legal disputes related to the allocation between the parties
 
of cost oil, tax oil and profit oil volumes. The
settlement agreement awards Equinor with an amicable compensation for overlifted volumes, which will
 
be payable over the 20-year
licence extension. The amounts and timing of payments to be received depend on a
 
number of factors related to operation of the field,
as well as future oil prices and production volumes. Equinor will consequently recognise settlement payments
 
when received, and no
amounts have been recognised in the Consolidated statement of income or Balance sheet for
 
2022. The parties are currently
undertaking necessary legal actions in order to formally close the legal disputes.
Claim from Petrofac regarding multiple variation order requests performed in Algeria (In Salah)
Petrofac International (UAE) LLC (“PIUL”) was awarded the EPC Contract to execute the ISSF
 
Project (the In Salah Southern Fields
Project which has finalised the development of 4 gas fields in central Algeria). Following suspension
 
of activity after the terrorist attack
at another gas field in Algeria (In Amenas) in 2013, PIUL issued multiple Variation Order Requests (“VoRs”) related to the costs
incurred for stand-by and remobilization costs after the evacuation of expatriates. Several VoRs have been paid, but the settlement of
the remaining has been unsuccessful. PIUL initiated arbitration in August 2020 claiming an estimated amount of
 
USD 533 million, of
which Equinor holds a 31.85% share. Equinor's maximum exposure amounts to USD 163 million. Equinor
 
has provided for its best
estimate in the matter.
Withholding tax dispute regarding remittances from Brazil to Norway
Remittances made from Brazil for services are normally subject to withholding income tax. In 2012, Equinor’s
 
subsidiaries in Brazil
filed a lawsuit to avoid paying this tax on remittances made to Equinor ASA and Equinor
 
Energy AS for services without transfer of
technology based on the Double Tax Treaty Brazil has with Norway.
 
Court proceedings through several levels in the legal system
have been ongoing since a first level decision in Equinor’s favour was
 
reached in 2013, and a final verdict has not yet been reached.
Withholding tax has not been paid since 2014.
 
Equinor's maximum exposure is estimated at approximately USD 146 million. Equinor
is of the view that all applicable tax regulations have been applied in the case and that Equinor
 
has a strong position. No amounts
have consequently been provided for in the financial statements.
Suit for an annulment of Petrobras’ sale of the interest in BM-S-8 to Equinor
In March 2017, an individual connected to the Union of Oil Workers of Sergipe (Sindipetro) filed a
 
class action suit against Petrobras,
Equinor, and ANP - the Brazilian Regulatory Agency - to seek annulment of Petrobras’ sale of the interest and operatorship in BM-S-8
to Equinor, which was closed in November 2016 after approval by the partners and authorities. In February 2022, sentence in the
annulment case was issued at the first instance level, and Equinor won on all merits. The
 
case was appealed by the plaintiff and
Equinor has filed counter arguments. At the end of 2022, the acquired interest remains in Equinor’s
 
balance sheet, where the assets
related to phase 1 have been reclassified to property, plant and equipment and the assets related to phase 2 are presented as
intangible assets, all of which are part of the Exploration & Production International (E&P International)
 
segment.
Brazilian law creating uncertainty regarding certain tax incentives
Equinor is currently part in two legal matters in the state of Rio de Janeiro in Brazil
 
related to a law requiring taxpayers that benefits
from ICMS tax incentives (i.e. Repetro) to deposit 10% of the savings made from
 
such benefits into a state fund. Equinor is of the
opinion that specific incentives so far relevant for the Roncador and Peregrino fields are not
 
in scope of the law, while the state of Rio
de Janeiro requires deposits to be paid with the addition of fines and interests. Several legal
 
actions to oppose the laws and related
payments have therefore been initiated by both Equinor’s peers and the Brazilian
 
Petroleum and Gas Institute (IBP). At year-end
2022, the maximum exposure for Equinor in these various matters has been estimated to a
 
total of USD 132 million. Equinor is of the
opinion that the law is unconstitutional, especially for Repetro incentives, and this will
 
be upheld in future legal proceedings. No
amounts have consequently been provided for in the financial statements.
KKD oil sands partnership
Canadian tax authorities have issued a notice of reassessment for 2014 for Equinor's Canadian
 
subsidiary which was party to
Equinor's divestment of 40% of the KKD Oil Sands partnership at that time. The reassessment,
 
which has been appealed, adjusts the
allocation of the proceeds of disposition of certain Canadian resource properties from the partnership. Maximum exposure
 
is
estimated to be approximately USD 372 million. The appeal process with the Canadian tax authorities,
 
as well as any subsequent
litigation that may become necessary, may take several years. No taxes will become payable until the matter has been finally settled.
222
 
Equinor, Annual Report on Form 20-F 2022
 
Equinor is of the view that all applicable tax regulations have been applied in the
 
case and that Equinor has a strong position. No
amounts have consequently been provided for in the financial statements.
Resolved dispute with Norwegian tax authorities related to Equinor Service Center Belgium
 
N.V
In the fourth quarter of 2020, Equinor received a decision from the Norwegian tax authorities
 
related to the capital structure of the
subsidiary Equinor Service Center Belgium N.V., concluding that the capital structure had to be based on the arm length’s principle,
affecting the fiscal years 2012 to 2016. Equinor received a claim of USD 182 million that was paid in
 
2021. During 2022, the tax
authorities reversed their decision and accepted Equinor’s initial position. The tax payment
 
has been reimbursed to Equinor, adjusted
for changes in tax rates. The adjustment, which has been recognised as tax expense in
 
the Consolidated statement of income in
2022, is considered immaterial.
Dispute with Norwegian tax authorities regarding R&D costs in the offshore tax regime
Equinor has an ongoing dispute regarding the level of Research & Development cost to be allocated
 
to the offshore tax regime.
During 2022, the Oil Taxation Office (OTO) informed Equinor that it had decided to accept Equinor’s position regarding certain
disputed items, resulting in a reduction in Equinor’s maximum exposure. Further, Equinor has accepted an increase
 
in taxable income
for both onshore and offshore tax. A previously recognised provision of USD 95 million has been reclassified
 
to current tax payable.
Equinor’s Income tax expense was not affected by this development, and the remaining expected
 
maximum exposure related to R&D
costs in the offshore tax regime is considered immaterial.
Dispute with Norwegian tax authorities regarding internal pricing of natural gas liquids
The Oil Taxation Office has challenged the internal pricing of certain products of natural gas liquids sold from Equinor Energy AS to
Equinor ASA in the years 2011-2020. During 2022 there has been development in various elements of these cases, where parts of
the previous exposure have been resolved or have reached the end of available appeal processes,
 
and other parts have been
appealed. Following these developments, which did not impact the Consolidated statement of income
 
significantly, the maximum
exposure regarding the gas liquid pricing remains at an estimated USD 71 million. Equinor
 
has provided for its best estimate in the
matter.
Other claims
During the normal course of its business, Equinor is involved in legal proceedings, and several other unresolved
 
claims are currently
outstanding. The ultimate liability or asset, in respect of such litigation and claims cannot
 
be determined at this time. Equinor has
provided in its Consolidated financial statements for probable liabilities related to litigation and
 
claims based on its best estimate.
Equinor does not expect that its financial position, results of operations or cash flows will be materially
 
affected by the resolution of
these legal proceedings. Equinor is actively pursuing the above disputes through the contractual
 
and legal means available in each
case, but the timing of the ultimate resolutions and related cash flows, if any, cannot at present be determined with sufficient reliability.
Provisions related to claims other than those related to income tax are reflected within note
 
23 Provisions and other liabilities.
Uncertain income tax related liabilities are reflected as current tax payables or deferred tax liabilities
 
as appropriate, while uncertain
tax assets are reflected as current or deferred tax assets.
Equinor, Annual Report on Form 20-F 2022
 
223
27 Related parties
Transactions with the Norwegian State
The Norwegian State is the majority shareholder of Equinor and also holds major
 
investments in other Norwegian companies. As of
 
31 December 2022, the Norwegian State had an ownership interest in Equinor of 67.0% (excluding
 
Folketrygdfondet, the Norwegian
national insurance fund, of 3.4%). This ownership structure means that Equinor participates in transactions
 
with many parties that are
under a common ownership structure and therefore meet the definition of a related party. The responsibility for the Norwegian State`s
shareholding in Equinor was transferred from the Ministry of Petroleum and Energy to the Ministry
 
of Trade and Industry on 1 January
2022.
Total purchases of oil and natural gas liquids from the Norwegian State amounted to USD 12,617 million, USD 9,572 million and USD
5,108 million in 2022, 2021
 
and 2020, respectively. These purchases of oil and natural gas liquids are recorded in Equinor ASA. In
addition, Equinor ASA sells in its own name, but for the Norwegian State’s account and risk, the
 
Norwegian State’s gas production.
These transactions are presented net. For further information please see note 7 Total revenues and other income. The most
significant items included in the line-item Payables to equity accounted associated companies and
 
other related parties in note 24
Trade and other payables, are amounts payable to the Norwegian State for these purchases.
The line-item Prepayments and Financial Receivables includes USD 1,461 million which represent a gross
 
receivable from the
Norwegian state under the Marketing Instruction in relation to the state’s (SDFI) expected participation in the gas sales
 
activities of a
foreign subsidiary of Equinor. At year end 2021 the corresponding amount was USD 435 million. The increase is mainly related to
increased volumes and higher cost price on the gas storage. A corresponding non-current
 
liability of USD 1,461 million has been
recognized, representing SDFI's estimated interest in the gas sales activities in the foreign
 
subsidiary.
Other transactions
In its ordinary business operations Equinor enters into contracts such as pipeline transport, gas storage
 
and processing of petroleum
products, with companies in which Equinor has ownership interests. Such transactions
 
are included within the applicable captions in
the Consolidated statement of income. Gassled and certain other infrastructure assets are
 
operated by Gassco AS, which is an entity
under common control by the Norwegian Ministry of Petroleum and Energy. Gassco’s activities are performed on behalf of and for the
risk and reward of pipeline and terminal owners, and capacity payments flow through Gassco to the respective
 
owners. Equinor
payments that flowed through Gassco in this respect amounted to USD 1,210 million, USD 1,030
 
million and USD 896 million in 2022,
2021 and 2020, respectively. These payments are mainly recorded in Equinor ASA. The stated amounts represent Equinor’s capacity
payment net of Equinor’s own ownership interests in Gassco operated infrastructure.
 
In addition, Equinor ASA manages, in its own
name, but for the Norwegian State’s account and risk, the Norwegian State’s share of the Gassco costs. These transactions
 
are
presented net. Equinor has had transactions with other associated companies and joint ventures
 
in the course of its ordinary
business, for which amounts have not been disclosed due to materiality. In addition, Equinor has had transactions with joint
operations and similar arrangements where Equinor is operator. Indirect operating expenses incurred as operator are charged to the
joint operation or similar arrangement based on the “no-gain/no-loss” principle.
Related party transactions with management are presented in note 8 Salaries and personnel
 
expenses
.
224
 
Equinor, Annual Report on Form 20-F 2022
 
28 Financial instruments and fair value measurement
Accounting policies
Financial assets
Financial assets are initially recognised at fair value when Equinor becomes a party to the contractual provisions
 
of the asset. The
subsequent measurement of the financial assets depends on which category they have been
 
classified into at inception: Financial
investments at amortised cost, at fair value through profit or loss, and at fair value through
 
other comprehensive income. The
classification is based on an evaluation of the contractual terms and the business model
 
applied.
Short-term highly liquid investments with original maturity exceeding 3 months are classified as
 
current financial investments. Current
financial investments are primarily accounted for at amortised cost but also at fair value through profit or loss,
 
depending on
classification.
Trade receivables are carried at the original invoice amount less a provision for doubtful receivables which represent expected losses
computed on a probability-weighted basis.
A part of Equinor's financial investments is managed together as an investment portfolio
 
of Equinor's captive insurance company and
is held in order to comply with specific regulations for capital retention. The investment portfolio
 
is managed and evaluated on a fair
value basis in accordance with an investment strategy and is accounted for at fair value through profit or loss.
Financial assets are presented as current if they contractually will expire or otherwise are expected
 
to be recovered within 12 months
after the balance sheet date, or if they are held for the purpose of being traded. Financial
 
assets and financial liabilities are shown
separately in the Consolidated balance sheet, unless Equinor has both a legal right and a demonstrable
 
intention to net settle certain
balances payable to and receivable from the same counterparty.
Financial assets are derecognised when rights to cash flows and risks and rewards
 
of ownership are transferred through a sales
transaction or the contractual rights to the cash flows expire, are redeemed, or cancelled. Gains
 
and losses arising on the sale,
settlement or cancellation of financial assets are recognised within Net financial items.
Financial liabilities
Financial liabilities are initially recognised at fair value when Equinor becomes a party to
 
the contractual provisions of the liability. The
subsequent measurement of financial liabilities is either as financial liabilities at fair value through
 
profit or loss or financial liabilities
measured at amortised cost using the effective interest method, depending on classification. The latter
 
applies to Equinor's non-
current bank loans and bonds.
Financial liabilities are presented as current if the liability is expected to be settled as
 
part of Equinor’s normal operating cycle, the
liability is due to be settled within 12 months after the balance sheet date, Equinor does
 
not have the right to defer settlement of the
liability more than 12 months after the balance sheet date, or if the liabilities are held for the
 
purpose of being traded.
Financial liabilities are derecognised when the contractual obligations are settled, or if they expire,
 
are discharged or cancelled. Gains
and losses arising on the repurchase, settlement or cancellation of liabilities are recognised within
 
Net financial items.
Derivative financial instruments
Equinor uses derivative financial instruments to manage certain exposures to fluctuations in foreign
 
currency exchange rates, interest
rates and commodity prices. Such derivative financial instruments are initially recognised at
 
fair value on the date on which a
derivative contract is entered into and are subsequently remeasured at fair value through profit
 
and loss. The impact of commodity-
based derivative financial instruments is recognised in the Consolidated statement of income as
 
Other revenues, as such derivative
instruments are related to sales contracts or revenue-related risk management for all significant purposes. The impact
 
of other
derivative financial instruments is reflected under Net financial items.
Derivatives are carried as assets when the fair value is positive and as liabilities when
 
the fair value is negative. Derivative assets or
liabilities expected to be settled, or with the legal right to be settled more than 12 months after
 
the balance sheet date, are classified
as non-current. Derivative financial instruments held for the purpose of being traded are however
 
always classified as current.
Contracts to buy or sell a non-financial item that can be settled net in cash or another
 
financial instrument are accounted for as
financial instruments. However, contracts that are entered into and continue to be held for the purpose of the receipt or delivery of a
non-financial item in accordance with Equinor's expected purchase, sale or usage requirements,
 
also referred to as own-use, are not
accounted for as financial instruments. Such sales and purchases of physical commodity
 
volumes are reflected in the Consolidated
statement of income as Revenue from contracts with customers and Purchases [net of inventory
 
variation], respectively. This is
applicable to a significant number of contracts for the purchase or sale of crude oil and natural gas,
 
which are recognised upon
delivery.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
225
For contracts to sell a non-financial item that can be settled net in cash, but which ultimately
 
are physically settled despite not
qualifying as own use prior to settlement, the changes in fair value are included in Gain/loss on
 
commodity derivatives (part of Other
revenues, see note 7 Total revenues and other income). When these derivatives are physically settled, the previously recognised
unrealised gain/loss is included in Physically settled commodity derivatives (also part of Other revenues).
 
The physical deliveries
made through such contracts are included in Revenue from contracts with customers at
 
contract price.
Derivatives embedded in host contracts which are not financial assets within the scope of IFRS
 
9 are recognised as separate
derivatives and are reflected at fair value with subsequent changes through profit and
 
loss, when their risks and economic
characteristics are not closely related to those of the host contracts, and the host contracts are not carried
 
at fair value. Where there is
an active market for a commodity or other non-financial item referenced in a purchase or sale contract,
 
a pricing formula will, for
instance, be considered to be closely related to the host purchase or sales contract if
 
the price formula is based on the active market
in question. A price formula with indexation to other markets or products will however result
 
in the recognition of a separate derivative.
Where there is no active market for the commodity or other non-financial item in question, Equinor
 
assesses the characteristics of
such a price related embedded derivative to be closely related to the host contract if
 
the price formula is based on relevant indexations
commonly used by other market participants. This applies to certain long-term natural gas sales
 
agreements.
--------------------------------------------------------------------------------------------------------------------------------------
Financial instruments by category
The following tables present Equinor's classes of financial instruments and their carrying amounts
 
by the categories as they are
defined in IFRS 9 Financial Instruments. For financial investments, the difference between measurement as defined by
 
IFRS 9
categories and measurement at fair value is immaterial. For trade and other receivables
 
and payables, and cash and cash
equivalents, the carrying amounts are considered a reasonable approximation of fair value. See note 21 Finance
debt for fair value
information of non-current bonds and bank loans.
At 31 December 2022
Fair value
through profit
or loss
Non-financial
assets
Total carrying
amount
(in USD million)
Note
Amortised cost
Assets
Non-current derivative financial instruments
 
691
691
Non-current financial investments
16
117
2,616
2,733
Prepayments and financial receivables
16
1,658
404
2,063
Trade and other receivables
18
21,611
841
22,452
Current derivative financial instruments
 
4,039
4,039
Current financial investments
16
29,577
300
29,876
Cash and cash equivalents
19
12,473
3,106
15,579
Total
 
65,436
10,752
1,245
77,433
At 31 December 2021
Fair value
through profit
or loss
Non-financial
assets
Total carrying
amount
(in USD million)
Note
Amortised cost
Assets
Non-current derivative financial instruments
 
1,265
1,265
Non-current financial investments
16
253
3,093
3,346
Prepayments and financial receivables
16
707
380
1,087
Trade and other receivables
18
17,192
736
17,927
Current derivative financial instruments
 
5,131
5,131
Current financial investments
16
20,946
300
21,246
Cash and cash equivalents
19
11,412
2,714
14,126
Total
 
50,510
12,503
1,116
64,128
 
226
 
Equinor, Annual Report on Form 20-F 2022
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
227
At 31 December 2022
Amortised
cost
Fair value
through
profit or loss
Non-financial
liabilities
Total
carrying
amount
(in USD million)
Note
Liabilities
Non-current finance debt
21
24,141
24,141
Non-current derivative financial instruments
 
2,376
2,376
Trade, other payables and provisions
24
12,449
903
13,352
Current finance debt
21
4,359
4,359
Dividend payable
2,808
2,808
Current derivative financial instruments
 
4,106
4,106
Total
 
43,757
6,482
903
51,142
At 31 December 2021
Amortised
cost
Fair value
through
profit or loss
Non-financial
liabilities
Total
carrying
amount
(in USD million)
Note
Liabilities
Non-current finance debt
21
27,404
27,404
Non-current derivative financial instruments
 
767
767
Trade, other payables and provisions
24
12,350
1,960
14,310
Current finance debt
21
5,273
5,273
Dividend payable
582
582
Current derivative financial instruments
 
4,609
4,609
Total
 
45,609
5,376
1,960
52,945
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
228
 
Equinor, Annual Report on Form 20-F 2022
 
Measurement of fair values
Quoted prices in active markets represent the best evidence of fair value and are used by Equinor
 
in determining the fair values of
assets and liabilities to the extent possible. Financial instruments quoted in active markets will
 
typically include financial instruments
with quoted market prices obtained from the relevant exchanges or clearing houses. The fair
 
values of quoted financial assets,
financial liabilities and derivative instruments are determined by reference to mid-market prices, at the
 
close of business on the
balance sheet date.
Where there is no active market, fair value is determined using valuation techniques. These include
 
using recent arm's-length market
transactions, reference to other instruments that are substantially the same, discounted cash flow
 
analysis, and pricing models and
related internal assumptions. In the valuation techniques, Equinor also takes into consideration the
 
counterparty and its own credit
risk. This is either reflected in the discount rate used or through direct adjustments to the calculated
 
cash flows. Consequently, where
Equinor reflects elements of long-term physical delivery commodity contracts at fair value, such fair value estimates to
 
the extent
possible are based on quoted forward prices in the market and underlying indexes in
 
the contracts, as well as assumptions of forward
prices and margins where observable market prices are not available. Similarly, the fair values of interest and currency swaps are
estimated based on relevant quotes from active markets, quotes of comparable instruments, and
 
other appropriate valuation
techniques.
Fair value hierarchy
The following table summarises each class of financial instruments which are recognised in the
 
Consolidated balance sheet at fair
value, split by Equinor's basis for fair value measurement.
(in USD million)
Non-current
financial
investments
Non-current
derivative
financial
instruments
- assets
Current
financial
investments
Current
derivative
financial
instruments
- assets
Cash
equivalents
Non-current
derivative
financial
instruments
- liabilities
Current
derivative
financial
instruments
- liabilities
Net fair
value
At 31 December 2022
Level 1
903
0
-
25
0
(60)
868
Level 2
1,222
97
300
3,722
3,106
(2,352)
(3,952)
2,143
Level 3
491
594
292
(24)
(94)
1,259
Total fair value
2,616
691
300
4,039
3,106
(2,376)
(4,106)
4,270
At 31 December 2021
Level 1
860
-
-
949
-
(69)
1,740
Level 2
1,840
884
300
4,108
2,714
(762)
(4,539)
4,545
Level 3
393
380
74
(4)
843
Total fair value
3,093
1,265
300
5,131
2,714
(767)
(4,609)
7,127
Level 1, fair value based on prices quoted in an active market for identical assets or liabilities,
 
includes financial instruments actively
traded and for which the values recognised in the Consolidated balance sheet are determined based
 
on observable prices on identical
instruments. For Equinor this category will, in most cases, only be relevant for investments in
 
listed equity securities and government
bonds.
Level 2, fair value based on inputs other than quoted prices included within level 1, which are derived
 
from observable market
transactions, includes Equinor's non-standardised contracts for which fair values are determined on the basis of
 
price inputs from
observable market transactions. This will typically be when Equinor uses forward prices
 
on crude oil, natural gas, interest rates and
foreign currency exchange rates as inputs to the valuation models to determine the fair value of it
 
derivative financial instruments.
Level 3, fair value based on unobservable inputs, includes financial instruments for which fair
 
values are determined on the basis of
input and assumptions that are not from observable market transactions. The fair
 
values presented in this category are mainly based
on internal assumptions. The internal assumptions are only used in the absence of quoted
 
prices from an active market or other
observable price inputs for the financial instruments subject to the valuation.
The fair value of certain earn-out agreements and embedded derivative contracts are determined
 
by the use of valuation techniques
with price inputs from observable market transactions as well as internally generated price assumptions
 
and volume profiles. The
discount rate used in the valuation is a risk-free rate based on the applicable currency and time horizon
 
of the underlying cash flows
adjusted for a credit premium to reflect either Equinor's credit premium, if the value is a liability, or an estimated counterparty credit
Equinor, Annual Report on Form 20-F 2022
 
229
premium if the value is an asset. In addition, a risk premium for risk elements not adjusted for in
 
the cash flow may be included when
applicable. The fair values of these derivative financial instruments have been classified in their
 
entirety in the third category within
current derivative financial instruments and non-current derivative financial instruments. Another reasonable
 
assumption, that could
have been applied when determining the fair value of these contracts, would be to extrapolate
 
the last observable forward prices with
inflation. If Equinor had applied this assumption, the fair value of the contracts included would
 
have increased by approximately USD
0.5 billion at end of 2022, while at end of 2021 the increase in fair value was approximately
 
USD 0.4 billion.
The reconciliation of the changes in fair value during 2022 and 2021 for financial instruments classified
 
as level 3 in the hierarchy is
presented in the following table.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
230
 
Equinor, Annual Report on Form 20-F 2022
 
(in USD million)
Non-current
financial
investments
Non-current
derivative
financial
instruments -
assets
Current
derivative
financial
instruments -
assets
Non-current
derivative
financial
instruments -
liabilities
Current
derivative
financial
instruments -
liabilities
Total amount
Opening at 1 January 2022
393
380
74
(4)
0
843
Total gains and losses recognised in statement of income
(50)
243
197
(20)
0
370
Purchases
175
10
(120)
65
Sales
-
-
2
-
22
24
Settlement
(7)
(64)
(71)
Transfer into level 3
-
80
5
85
Foreign currency translation effects
(19)
(30)
(7)
(1)
(57)
Closing at 31 December 2022
492
593
292
(24)
(94)
1,259
Opening at 1 January 2021
308
330
24
(5)
-
657
Total gains and losses recognised in statement of income
(23)
58
72
1
-
108
Purchases
119
119
Settlement
(7)
(20)
(27)
Transfer out of level 3
-
-
Foreign currency translation effects
(3)
(8)
(2)
(13)
Closing at 31 December 2021
393
380
74
(4)
-
843
During 2022 the financial instruments within level 3 have had a net increase in fair value of USD 416 million.
 
The USD 370 million
recognised in the Consolidated statement of income during 2022 are mainly related to changes
 
in fair value of certain embedded
derivatives and earn-out agreements.
29 Subsequent events
Agreement to acquire Suncor Energy UK Limited
On 3 March 2023, Equinor entered into an agreement to acquire 100% of Suncor Energy UK
 
Limited for a total consideration of USD
850 million before adjustments for working capital and net cash. USD 250 million is contingent on final
 
investment decision on the
Rosebank field. The transaction includes a non-operated interest in the producing Buzzard oil field (29.89%)
 
and an additional interest
in the operated Rosebank development (40%). Closing of the transaction is expected in the first
 
half of 2023 subject to relevant
regulatory approvals and will be recognised in the E&P International segment.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
231
4.3 Parent company financial statements
STATEMENT
 
OF INCOME EQUINOR ASA
Full year
(in USD million)
Note
2022
2021
Revenues
3
 
68,154
 
 
50,088
 
Net income/(loss) from subsidiaries and other equity accounted investments
10
 
28,630
 
 
9,806
 
Other income
 
 
0
 
 
1
 
 
Total
 
revenues and other income
 
 
96,784
 
 
59,894
 
 
Purchases [net of inventory variation]
 
 
(64,932)
 
(47,742)
Operating expenses
 
 
(2,499)
 
(1,493)
Selling, general and administrative expenses
 
 
(342)
 
(280)
Depreciation, amortisation and net impairment losses
9
 
(623)
 
(589)
Exploration expenses
 
(23)
 
(47)
Total
 
operating expenses
 
(68,419)
 
(50,151)
Net operating income/(loss)
 
 
28,365
 
 
9,744
 
Interest expenses and other finance expenses
 
(1,889)
 
(1,088)
Other financial items
 
1,002
 
 
(771)
 
Net financial items
7
 
(888)
 
(1,860)
 
Income/(loss) before tax
 
 
27,477
 
 
7,884
 
 
Income tax
8
 
68
 
 
278
 
 
Net income/(loss)
 
 
27,546
 
 
8,162
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
232
 
Equinor, Annual Report on Form 20-F 2022
 
STATEMENT
 
OF COMPREHENSIVE INCOME EQUINOR ASA
Full year
(in USD million)
Note
2022
2021
Net income/(loss)
27,546
8,162
Actuarial gains/(losses) on defined benefit pension
 
plans
461
147
Income tax effect on income and expense recognised
 
in OCI
1)
(105)
(35)
Items that will not be reclassified to the Statement
 
of income
17
356
111
Foreign currency translation effects
(2,389)
(645)
Share of OCI from equity accounted investments
10
424
0
Items that may subsequently be reclassified to the Statement
 
of income
(1,965)
(645)
Other comprehensive income/(loss)
(1,609)
(534)
Total comprehensive income/(loss)
25,937
7,629
Attributable to the equity holders of the company
25,937
7,629
1) Other Comprehensive Income (OCI).
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
233
BALANCE SHEET EQUINOR ASA
At 31
December
(in USD million)
Note
2022
2021
ASSETS
Property, plant and equipment
9, 20
 
2,021
 
 
1,834
 
Intangible assets
 
 
4
 
 
2
 
Investments in subsidiaries and other equity accounted companies
10
 
50,548
 
 
36,316
 
Deferred tax assets
8
 
1,354
 
 
1,117
 
Pension assets
17
 
1,163
 
 
1,359
 
Derivative financial instruments
2
 
95
 
 
900
 
Financial investments
 
166
 
 
363
 
Prepayments and financial receivables
 
 
1,838
 
 
839
 
Receivables from subsidiaries and other equity accounted companies
11
 
19,129
 
 
18,755
 
 
Total non-current assets
 
 
76,319
 
 
61,485
 
 
Inventories
12
 
1,771
 
 
2,676
 
Trade and other receivables
13
 
14,190
 
 
13,464
 
Receivables from subsidiaries and other equity accounted companies
11
 
26,413
 
 
19,841
 
Derivative financial instruments
2
 
979
 
 
1,719
 
Financial investments
11
 
29,466
 
 
20,946
 
Cash and cash equivalents
14
 
10,204
 
 
10,850
 
 
Total current assets
 
 
83,023
 
 
69,495
 
 
Total assets
 
 
159,342
 
 
130,980
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
234
 
Equinor, Annual Report on Form 20-F 2022
 
BALANCE SHEET EQUINOR ASA
At 31
December
(in USD million)
Note
2022
2021
EQUITY AND LIABILITIES
Share capital
 
 
1,142
 
 
1,164
 
Additional paid-in capital
 
 
0
 
 
3,231
 
Reserves for valuation variances
 
 
8,705
 
 
29
 
Reserves for unrealised gains
 
 
131
 
 
906
 
Retained earnings
 
 
40,936
 
 
32,098
 
 
Total
 
equity
15
 
50,914
 
 
37,428
 
 
Finance debt
16
 
24,141
 
 
27,404
 
Lease liabilities
20
 
1,269
 
 
1,209
 
Liabilities to subsidiaries and other equity accounted companies
 
 
315
 
 
159
 
Pension liabilities
17
 
3,656
 
 
4,378
 
Provisions and other liabilities
18
 
1,841
 
 
674
 
Derivative financial instruments
2
 
2,376
 
 
767
 
 
Total non-current liabilities
 
 
33,598
 
 
34,591
 
 
Trade, other payables and provisions
19
 
4,037
 
 
4,326
 
Current tax payable
 
255
 
 
1
 
Finance debt
16
 
2,786
 
 
3,743
 
Lease liabilities
20
 
528
 
 
487
 
Dividends payable
15
 
5,608
 
 
1,870
 
Liabilities to subsidiaries and other equity accounted companies
11
 
59,587
 
 
47,360
 
Derivative financial instruments
2
 
2,029
 
 
1,176
 
 
Total current liabilities
 
 
74,830
 
 
58,961
 
 
Total liabilities
 
108,428
93,552
Total equity and liabilities
159,342
130,980
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
235
STATEMENT
 
OF CASH FLOWS EQUINOR ASA
Full year
(in USD million)
Note
2022
2021
Income/(loss) before tax
 
27,477
 
 
7,884
 
Depreciation, amortisation and net impairment
9
 
623
 
 
589
 
(Gains)/losses on foreign currency transactions and balances
 
(756)
 
389
 
(Income)/loss from equity accounted subsidiaries and investments without cash effects
 
(20,758)
 
(5,276)
(Increase)/decrease in other items related to operating activities
 
(321)
 
794
 
(Increase)/decrease in net derivative financial instruments
2
 
561
 
 
2,023
 
Interest received
 
1,059
 
 
759
 
Interest paid
 
(1,763)
 
(1,054)
Cash flows provided by operating activities before taxes paid and working capital items
 
6,122
 
 
6,108
 
Taxes paid
 
135
 
 
(216)
(Increase)/decrease in working capital
 
2,665
 
 
(2,974)
Cash flows provided by operating activities
 
8,923
 
 
2,918
 
Capital expenditures and investments
9, 10
 
(5,823)
 
(815)
(Increase)/decrease in financial investments
 
(9,937)
 
(10,148)
(Increase)/decrease in derivative financial instruments
 
1,930
 
 
(45)
(Increase)/decrease in other interest bearing items
 
8
 
 
12
 
(Increase)/decrease in financial receivables from group companies
1)
 
4,553
 
 
(4,336)
Proceeds from sale of assets and businesses and capital contribution received
 
202
 
 
340
 
Cash flows provided by/(used in) investing activities
 
(9,069)
 
(14,992)
Repayment of finance debt
16
 
(250)
 
(2,675)
Repayment of lease liabilities
20
 
(588)
 
(517)
Dividends paid
15
 
(5,380)
 
(1,797)
Share buy-back
15
 
(3,315)
 
(321)
Net current finance debt and other financing activities
 
(5,690)
 
915
 
Increase/(decrease) in financial receivables and payables to/from subsidiaries
2)
 
16,431
 
 
23,063
 
Cash flows provided by/(used in) financing activities
 
1,208
 
 
18,667
 
Net increase/(decrease) in cash and cash equivalents
 
1,062
 
 
6,594
 
Foreign currency translation effects
 
(1,568)
 
(560)
Cash and cash equivalents at the beginning of the period (net of overdraft)
14
 
10,710
 
 
4,676
 
Cash and cash equivalents at the end of the period (net of overdraft)
3)
14
 
10,204
 
 
10,710
 
1) (Increase)/decrease in financial receivables from group companies are separated from the line (increase)/decrease
 
in
other interest bearing items and 2021 has been reclassified.
2) Mainly deposits in Equinor group's internal bank arrangement.
3) At 31 December 2022 cash and cash equivalents net overdraft were zero.
 
At 31 December 2021 cash and cash
equivalents included a net overdraft of USD 140 million.
 
236
 
Equinor, Annual Report on Form 20-F 2022
 
Notes to the Financial statements Equinor ASA
1 Organisation and significant accounting policies
Equinor ASA is the parent company of the Equinor Group (Equinor), consisting of Equinor ASA
 
and its subsidiaries. Equinor ASA’s
main activities include shareholding in group companies, group management, corporate functions and group financing.
 
Equinor ASA
also carries out activities related to external sales of oil and gas products, purchased externally
 
or from group companies, including
related refinery and transportation activities. Reference is made to disclosure
 
note 1 Organisation in Equinor’s Consolidated financial
statements.
The financial statements of Equinor ASA ("the company") are prepared in accordance with
 
simplified IFRS pursuant to the Norwegian
Accounting Act §3-9 and regulations regarding simplified application of IFRS issued by the Norwegian Ministry
 
of Finance on 7
February 2022. The presentation currency of Equinor ASA is US dollar (USD),
 
consistent with the presentation currency for the group
financial statements and with the company’s functional currency, as USD is the currency for which Equinor’s operations are mainly
linked to. Translation currency rates (NOK/USD) applicable for the period are as follows: 8.82 (31 Dec 2021), 9.86 (31 Dec
 
2022) and
9.62 (year-average).
These parent company financial statements should be read in connection with the Consolidated
 
financial statements of Equinor,
published together with these financial statements. With the exceptions described below, Equinor ASA applies the accounting policies
of the group, as described in Equinor’s Consolidated financial statements.
 
Insofar that the company applies policies that are not
described in the Equinor consolidated financial statements due to group level materiality considerations,
 
such policies are included
below if necessary for a sufficient understanding of Equinor ASA’s accounts.
Subsidiaries, associated companies and joint ventures
Shareholdings and interests in subsidiaries and associated companies (companies in which Equinor ASA
 
does not have control, or
joint control, but has the ability to exercise significant influence over operating and financial policies, generally
 
when the ownership
share is between 20% and 50%), as well as Equinor ASA’s participation in joint arrangements that are joint ventures, are accounted
for using the equity method. Under the equity method, the investment is carried on the
 
balance sheet at cost plus post-acquisition
changes in Equinor ASA’s share of net assets of the entity, less distribution received and less any impairment in value of the
investment. Goodwill may arise as the surplus of the cost of investment over Equinor ASA’s share of the net fair value of the
identifiable assets and liabilities of the subsidiary, joint venture or associate. Goodwill included in the balance sheets of subsidiaries
and associated companies is tested for impairment as part of the related investment
 
in the subsidiary or associated company. The
Statement of income reflects Equinor ASA’s share of the results after tax of an equity-accounted entity, adjusted to account for
depreciation, amortisation and any impairment of the equity-accounted entity’s assets based on their fair
 
values at the date of
acquisition in situations where Equinor ASA has not been the owner since the establishment
 
of the entity. Net income/loss from equity
accounted investments is presented as part of Total revenues and other income, as these investments in other companies engaged in
energy-related business activities are considered part of Equinor ASA’s main operating activities.
Within Equinor ASA’s equity,
 
a reserve for valuation variances has been established. All positive differences between the equity
accounted investments’ carrying value and the acquisition cost is allocated to this reserve.
Expenses related to the Equinor group as operator of joint operations and similar
 
arrangements (licences)
Indirect operating expenses incurred by the company, such as personnel expenses, are accumulated in cost pools. Such expenses
are allocated in part on hours incurred cost basis to Equinor Energy AS, to other
 
group companies and to licences where Equinor
Energy AS or other group companies are operators. Costs allocated in this manner reduce
 
the expenses in the company's statement
of income, with the exception of operating subleases and cost recharges related to lease liabilities
 
being recognised gross, which are
presented as revenues in Equinor ASA.
Asset transfers between the company and its subsidiaries
Transfers of assets and liabilities between the company and the entities that it directly or indirectly controls are accounted for at the
carrying amounts (continuity) of the assets and liabilities transferred, when the transfer is part of
 
a reorganisation within the Equinor
group.
Embedded derivatives
Embedded derivatives within sales or purchase contracts between Equinor ASA
 
and other companies within the Equinor group are
not separated from the host contract.
Dividends payable and group contributions
Dividends are reflected as Dividends payable within current liabilities. Group contributions for
 
the year to other entities within Equinor's
Norwegian tax group are reflected in the balance sheet as current liabilities within
 
Liabilities to group companies. Under simplified
IFRS the presentation of dividends payable and group contributions payable differs from the presentation under
 
IFRS, as it also
includes dividends and group contributions payable which at the date of the balance sheet is
 
subject to a future annual general
meeting approval before distribution.
Reserves for unrealised gains
Reserves for unrealised gains included within the Company’s equity consists of accumulated unrealised
 
gains on non-exchange
traded financial instruments and accumulated positive fair value changes from embedded derivatives.
Equinor, Annual Report on Form 20-F 2022
 
237
2 Financial risk management and measurement of financial instruments
General information relevant to financial risks
Equinor ASA's activities expose the company to market risk, liquidity risk and credit risk. The management of such
 
risks does not
substantially differ from the Group’s. See note 4
Financial risk and capital management in the Consolidated financial statements.
Measurement of financial instruments by categories
The following tables present Equinor ASA's classes of financial instruments and their carrying
 
amounts by the categories as they are
defined in IFRS 9 Financial Instruments. For financial investments, the difference between measurement as defined by
 
IFRS 9
categories and measurement at fair value is immaterial. For trade and other receivables and
 
payables and cash and cash equivalents,
the carrying amounts are considered a reasonable approximation of fair value.
See note 21 Finance debt in the Consolidated financial statements for fair value information
 
of non-current bonds and bank loans and
note 28 Financial instruments and fair value measurement in the Consolidated financial
 
statements where fair value measurement is
explained in detail.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
238
 
Equinor, Annual Report on Form 20-F 2022
 
(in USD million)
Note
Amortised
cost
Fair value
through profit
or loss
Non-
financial
assets
Total
carrying
amount
At 31 December 2022
Assets
Non-current derivative financial instruments
 
95
95
Non-current financial investments
166
166
Prepayments and financial receivables
 
1,645
193
1,838
Receivables from subsidiaries and other equity accounted
 
companies
11
18,563
566
19,129
Trade and other receivables
13
13,963
227
14,190
Receivables from subsidiaries and other equity accounted
 
companies
11
26,363
50
26,413
Current derivative financial instruments
 
979
979
Current financial investments
11
29,466
29,466
Cash and cash equivalents
14
7,098
3,106
10,204
Total financial assets
97,098
4,346
1,037
102,481
(in USD million)
Note
Amortised
cost
Fair value
through profit
or loss
Non-
financial
assets
Total
carrying
amount
At 31 December 2021
Assets
Non-current derivative financial instruments
 
900
900
Non-current financial investments
363
363
Prepayments and financial receivables
 
645
194
839
Receivables from subsidiaries and other equity accounted
 
companies
11
18,631
124
18,755
Trade and other receivables
13
13,284
179
13,464
Receivables from subsidiaries and other equity accounted
 
companies
11
19,795
46
19,841
Current derivative financial instruments
 
1,719
1,719
Current financial investments
11
20,946
20,946
Cash and cash equivalents
14
8,136
2,714
10,850
Total financial assets
81,437
5,697
543
87,677
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
239
(in USD million)
Not
e
Amortised
cost
Fair value
through
profit or
loss
Non-
financial
liabilities
Total carrying
amount
At 31 December 2022
Liabilities
Non-current finance debt
16
24,141
24,141
Liabilities to subsidiaries and other equity accounted
 
companies
25
291
315
Non-current derivative financial instruments
 
2,376
2,376
Trade and other payables
19
3,707
329
4,037
Current finance debt
16
2,786
2,786
Dividends payable
5,608
5,608
Liabilities to subsidiaries and other equity accounted
 
companies
11
59,587
59,587
Current derivative financial instruments
 
2,029
2,029
Total financial liabilities
95,854
4,405
620
100,879
(in USD million)
Not
e
Amortised
cost
Fair value
through
profit or
loss
Non-
financial
liabilities
Total carrying
amount
At 31 December 2021
Liabilities
Non-current finance debt
16
27,404
27,404
Liabilities to subsidiaries and other equity accounted
 
companies
26
134
159
Non-current derivative financial instruments
 
767
767
Trade and other payables
19
4,142
184
4,326
Current finance debt
16
3,743
3,743
Dividends payable
1,870
1,870
Liabilities to subsidiaries and other equity accounted
 
companies
11
47,360
47,360
Current derivative financial instruments
 
1,176
1,176
Total financial liabilities
84,545
1,943
317
86,804
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
240
 
Equinor, Annual Report on Form 20-F 2022
 
Financial instruments recognised at fair value through profit or loss, with a net fair value of USD -59
 
million in 2022 and USD 3,754
million in 2021, are mainly classified within Level 1 and Level 2 categories in the Fair Value hierarchy.
The following table contains the estimated fair values of Equinor ASA’s derivative financial instruments split by type.
Fair value
of assets
Fair value
of liabilities
 
Net fair
value
(in USD million)
At 31 December 2022
Foreign currency instruments
 
82
 
 
(595)
 
(514)
Interest rate instruments
 
56
 
 
(2,418)
 
(2,362)
Crude oil and refined products
 
31
 
 
(12)
 
19
 
Natural gas and electricity
 
 
905
 
 
(1,380)
 
(475)
Total fair value
 
1,074
 
 
(4,405)
 
(3,331)
At 31 December 2021
Foreign currency instruments
 
408
 
 
(98)
 
310
 
Interest rate instruments
 
884
 
 
(762)
 
122
 
Crude oil and refined products
 
60
 
 
(34)
 
26
 
Natural gas and electricity
 
 
1,267
 
 
(1,048)
 
219
 
Total fair value
 
2,620
 
 
(1,943)
 
677
 
Sensitivity analysis of market risk
Commodity price risk
Equinor ASA's assets and liabilities resulting from commodity based derivative contracts consist of both exchange
 
traded and non-
exchange traded instruments mainly in crude oil, refined products and natural gas.
Price risk sensitivities at the end of 2022 and 2021 at 30% are assumed to represent a reasonably possible change based
 
on the
duration of the derivatives.
At 31 December
2022
2021
(in USD million)
- 30%
+ 30%
- 30%
+ 30%
Crude oil and refined products net gains/(losses)
342
(342)
556
(556)
Natural gas and electricity net gains/(losses)
530
(530)
121
(121)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
241
Currency risk
The following currency risk sensitivity has been calculated by assuming a 12% reasonable possible change
 
in the main foreign
currency exchange rates that impact Equinor ASA’s financial accounts, based on balances at 31 December 2022. At 31 December
2021, a change of 10% in the most relevant foreign currency exchange rates was
 
viewed as a reasonable possible change. With
reference to the table below, an increase in the foreign currency exchange rates means that the disclosed currency has strengthened
in value against USD. The estimated gains and the estimated losses following from a change in the
 
foreign currency exchange rates
would impact the company’s statement of income.
The currency risk sensitivity of Equinor ASA mainly differs from that of the Group due to interest
 
bearing receivables and liabilities
from/to subsidiaries. For more detailed information about these receivables and liabilities, see
 
note 11 Financial assets and liabilities.
Currency risk sensitivity
At 31 December
2022
2021
(in USD million)
- 12%
+ 12%
- 10%
+ 10%
NOK net gains/(losses)
115
(115)
193
(193)
GBP net gains/(losses)
69
(69)
394
(394)
EUR net gains/(losses)
243
(243)
(177)
177
BRL net gains/(losses)
(519)
519
(240)
240
Interest rate risk
The following interest rate risk sensitivity has been calculated by assuming a change of 1.2 percentage
 
points as a reasonable
possible change in interest rates at the end of 2022. A change of 0.8 percentage
 
points in interest rates was viewed as a reasonable
possible change in 2021. The estimated gains following from a decrease in the interest rates and
 
the estimated losses following from
an interest rate increase would impact the company’s statement of income.
Interest risk sensitivity
At 31 December
2022
2021
(in USD million)
 
- 1.2 percentage
points sensitivity
+ 1.2 percentage
points sensitivity
 
- 0.8 percentage
points sensitivity
+ 0.8 percentage
points sensitivity
Positive/(negative) impact on net financial items
795
(795)
581
(581)
Equity price risk
The following equity price risk sensitivity has been calculated by assuming a 35% reasonable possible
 
change in equity prices that
impact Equinor ASA’s financial accounts, based on balances at 31 December 2022. At 31 December 2021, a change of 35% was
equally viewed as a reasonable possible change in equity prices. The estimated losses following
 
from a decrease in the equity prices
and the estimated gains following from an increase in equity prices would impact the company’s statement
 
of income.
Equity price sensitivity
At 31 December
2022
2021
(in USD million)
- 35%
+ 35%
- 35%
+ 35%
Net gains/(losses)
(58)
58
(127)
127
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
242
 
Equinor, Annual Report on Form 20-F 2022
 
3 Revenues
Full year
(in USD million)
2022
2021
Revenues third party
 
65,386
 
 
45,251
 
Intercompany revenues
 
2,768
 
 
4,837
 
Revenues
 
 
68,154
 
 
50,088
 
4 Salaries and personnel expenses
Equinor ASA remuneration
(amounts in USD million)
2022
2021
Salaries
1)
2,428
2,493
Pension cost
2)
416
446
Social security tax
357
348
Other compensations and social costs
266
229
Total remuneration
3,467
3,516
Average number of employees
3)
18,700
18,400
1) Salaries include bonuses and expatriate costs in addition to base pay.
2) See note 17 Pensions.
3) Part time employees amount to 2% for 2022 and 3% for 2021.
Total payroll expenses are accumulated in cost-pools and charged to partners of Equinor operated licences and group companies on
an hours incurred basis. For further information see note 22 Related parties.
Compensation to and share ownership of the board of directors (BoD), the corporate
 
executive committee (CEC) and the
corporate assembly
Compensation to the BoD during 2022 was USD 0.8 million and the total share ownership
 
of the members of the BoD at the end of
the year was 18,106 shares. Compensation to the CEC during 2022 was USD 12.7 million and the
 
total share ownership of the
members of the CEC at the end of the year was 247,535 shares. Compensation to the corporate assembly during 2022 was
 
USD 0.1
million and the total share ownership of the members of the corporate assembly at the
 
end of the year was 27,155 shares.
At 31 December 2022 and 2021 there are no loans to the members of the BoD or
 
the CEC.
The report of the remuneration to the board of directors and the corporate executive committee
 
for 2022 is available at
Equinor.com/Reports. The compensation policy applicable for 2022 and 2023 and the 2022 compensation report are no longer
included in the governance report and will be presented as a separate document on Equinor.com/Reports.
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
243
Severance pay arrangements
The chief executive officer and the executive vice presidents are entitled to a severance payment equivalent to
 
six months’ salary,
commencing after the six months’ notice period, when the resignation is requested by the company. The same amount of severance
payment is also payable if the parties agree that the employment should be discontinued, and the
 
executive vice president gives
notice pursuant to a written agreement with the company. Any other payment earned by the executive vice president during the period
of severance payment will be fully deducted. This relates to earnings from any employment or
 
business activity where the executive
vice president has active ownership.
The entitlement to severance payment is conditional on the chief executive officer or the executive vice president
 
not being guilty of
gross misconduct, gross negligence, disloyalty or other material breach of his/her duties.
The chief executive officer’s/executive vice president’s own notice will not instigate any severance payment.
5 Share-based compensation
Equinor's share saving plan provides employees with the opportunity to purchase Equinor shares through monthly
 
salary deductions.
If the shares are kept for two full calendar years of continued employment, following the year
 
of purchase, the employees will be
allocated one bonus share for each one they have purchased.
Estimated compensation expense including the contribution by Equinor ASA for purchased shares, amounts
 
vested for bonus shares
granted and related social security tax was USD 77 million in 2022, and USD 70 million in
 
2021. For the 2023 programme (granted in
2022), the estimated compensation expense is USD 69 million. At 31 December 2022, the amount
 
of compensation cost yet to be
expensed throughout the vesting period is USD 156 million.
6 Auditor’s remuneration
Auditor's remuneration
(in USD million, excluding VAT)
2022
2021
Audit fee
5.1
6.9
Audit related fee
0.5
0.1
Total remuneration
5.6
7.1
There are no fees incurred related to tax advice or other services.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
244
 
Equinor, Annual Report on Form 20-F 2022
 
7 Financial items
Full year
(in USD million)
2022
2021
Foreign currency exchange gains/(losses) derivative
 
financial instruments
 
809
861
Other foreign currency exchange gains/(losses)
(53)
(1,250)
Net foreign currency exchange gains/(losses)
756
(389)
Interest income from group companies
1,218
759
Interest income other current financial assets and other
 
financial items
960
38
Interest income and other financial items
2,178
797
Gains/(losses) financial investments
(187)
(471)
Gains/(losses) other derivative financial instruments
(1,745)
(708)
Interest expense to group companies
(710)
(76)
Interest expense non-current finance debt and lease liabilities
(1,069)
(943)
Interest expense current financial liabilities and
 
other finance expenses
(110)
(69)
Interest expenses and other finance expenses
(1,889)
(1,088)
Net financial items
(888)
(1,860)
Equinor's main financial items relate to assets and liabilities categorised in the fair value through
 
profit or loss category and the
amortised cost category. For more information about financial instruments by category see note 2 Financial risk management and
measurement of financial instruments.
Foreign currency exchange gains/(losses) derivative financial instruments include fair value changes of currency
 
derivatives related to
liquidity and currency risk. The line item Other foreign currency exchange gains/(losses) includes
 
a fair value loss from derivatives
related to non-current debt of USD 691 million in 2022 and USD 702 million in 2021.
The line item Gains/(losses) financial investments include a net loss of USD 194 million and USD 471 million
 
in 2022 and 2021,
respectively, from non-current financial investments in the fair value through profit or loss category.
The line item Gains/(losses) other derivative financial instruments primarily includes fair value changes from interest
 
rate related
derivatives. For 2022, a loss of USD 1,760 million is included,
 
corresponding to a loss of USD 724 million in 2021.
The line item Interest expense non-current finance debt and lease liabilities primarily includes two
 
main items; interest expense of
USD 912 million and USD 992 million, from the financial liabilities at amortised cost category, for 2022 and 2021, respectively; and net
interest expense of USD
111
million and net interest income of USD 94 million, on related derivatives from the fair value through
 
profit
or loss category, for 2022 and 2021, respectively.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
245
8 Income taxes
Income tax
Full year
(in USD million)
2022
2021
Current taxes
 
(233)
 
17
 
Change in deferred tax
 
301
 
 
261
 
Income tax
 
68
 
 
278
 
Reconciliation of Norwegian statutory tax rate to effective tax rate
Full year
(in USD million)
2022
2021
Income/(loss) before tax
 
27,477
 
 
7,884
 
Nominal tax rate
1)
 
(6,045)
 
(1,735)
Tax effect
 
of:
Permanent differences caused by NOK being the tax currency
 
50
 
 
22
 
Tax effect
 
of permanent differences related to equity accounted companies
 
6,289
 
 
2,183
 
Other permanent differences
 
(36)
 
(161)
Income tax prior years
 
(16)
 
14
 
Other
 
(172)
 
(46)
Income tax
 
68
 
 
278
 
Effective tax rate
(0.2%)
(3.5%)
1)
 
Statutory tax rate is 22% for 2022 and 2021.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
246
 
Equinor, Annual Report on Form 20-F 2022
 
Significant components of deferred tax assets and liabilities were as follows:
At 31 December
(in USD million)
2022
2021
Deferred tax assets
Tax
 
losses carry forward
 
0
 
 
152
 
Pensions
 
588
 
 
709
 
Interest limitation carry forward
 
11
 
 
104
 
Derivatives
 
623
 
 
21
 
Lease liabilities
 
380
 
 
353
 
Other
 
146
 
 
121
 
Total deferred tax assets
 
1,749
 
 
1,460
 
Deferred tax liabilities
Property, plant and equipment
 
394
 
 
344
 
Total deferred tax liabilities
 
394
 
 
344
 
Net deferred tax assets
1)
 
1,355
 
 
1,117
 
1)
 
At 31 December 2022, Equinor ASA had recognised net deferred tax assets of 1,4 billion USD,
 
as it is considered probable that
taxable profit will be available to utilise the deferred tax assets.
Movement in deferred tax
(in USD million)
2022
2021
Deferred tax assets at 1 January
 
1,117
 
 
915
 
Charged to the Statement of income
 
301
 
 
261
 
Actuarial losses pension
 
 
(98)
 
(25)
Group contribution
 
0
 
 
(34)
Other
 
34
 
 
0
 
Deferred tax assets at 31 December
 
1,355
 
 
1,117
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
247
9 Property, plant and equipment
(in USD million)
Machinery,
equipment and
transportation
equipment
Buildings
and land
Other
Right of
use
assets
3)
Total
Cost at 1 January 2022
748
289
160
3,175
4,372
Additions and transfers
23
3
0
783
809
Disposals at cost
(0)
0
0
(215)
(215)
Cost at 31 December 2022
771
292
160
3,743
4,966
Accumulated depreciation and impairment losses
 
at 1 January 2022
(691)
(157)
(153)
(1,538)
(2,538)
Depreciation
(31)
(14)
(1)
(576)
(622)
Accumulated depreciation and impairment on disposed
 
assets
0
0
0
215
215
Accumulated depreciation and impairment losses
 
at 31 December 2022
(722)
(170)
(154)
(1,899)
(2,945)
Carrying amount at 31 December 2022
49
121
6
1,844
2,021
Estimated useful lives (years)
3 - 10
10 - 33
1)
1 - 19
2)
1)
 
Land is not depreciated. Buildings include
 
leasehold improvements.
 
2)
 
Depreciation linearly over contract period.
3)
 
Right of use assets as per 31 December
 
2022 consist of Vessels USD 1,032 million, Land and buildings
 
USD 702 million and Storage
facilities USD 111 million.
10 Investments in subsidiaries and other equity accounted companies
(in USD million)
2022
2021
Investments at 1 January
 
36,316
 
 
35,464
 
Net income/(loss) from subsidiaries and other equity accounted investments
 
28,630
 
 
9,806
 
Increase/(decrease) in paid-in capital
 
5,794
 
 
417
 
Distributions
 
(18,206)
 
(8,752)
Share of OCI from equity accounted investments
 
423
 
 
28
 
Foreign currency translation effects
 
(2,388)
 
(645)
Divestment
 
(20)
 
(2)
Other
 
(0)
 
0
 
Investments at 31 December
 
50,548
 
 
36,316
 
In the fourth quarter of 2021, Equinor ASA entered into an agreement with Vermilion Energy Inc (Vermilion) to sell Equinor ASA’s non-
operated equity position in the Corrib gas project in Ireland. The transaction covers a sale of 100%
 
of the shares in Equinor Energy
Ireland Limited (EEIL). EEIL owns 36.5% of the Corrib field alongside the operator Vermilion (20%) and Nephin Energy (43.5%).
Equinor ASA and Vermilion have agreed a consideration of USD 434 million before closing adjustments and contingent consideration
linked to 2022 production level and gas prices. Closing is dependent on governmental approval
 
and is expected to take place during
the first quarter 2023.
The closing balance of investments at 31 December 2022 of USD 50,548 million, consists of investments
 
in subsidiaries amounting to
USD 50,483 million and investments in other equity accounted companies amounting to USD 65 million.
 
In 2021, the amounts were
USD 36,255 million and USD 60 million respectively.
 
 
 
 
 
 
 
 
 
248
 
Equinor, Annual Report on Form 20-F 2022
 
The foreign currency translation adjustments relate to currency translation effects from subsidiaries with functional
 
currencies other
than USD.
In 2022, Net income/(loss) from subsidiaries and other equity accounted investments were impacted by net impairment
 
reversals of
USD 1,241 million after tax mainly caused by increased price estimates partially offset by the effect from the decision to exit Russia
which amounted to USD 994 million after tax.
In 2021, Net income/(loss) from subsidiaries and other equity accounted investments were impacted by net impairment
 
losses of USD
1,369 million after tax mainly caused by downward reserve revisions and increased carbon cost
 
estimates partially offset by
impairment reversals due to higher gas price estimates.
Increase/(decrease) in paid-in capital in 2022 mainly consist of equity contributions from Equinor ASA
 
to Equinor Refining Norway AS
of USD 4,145 million, Equinor New Energy AS of USD 974 million and Equinor UK
 
Ltd of USD 629 million.
Increase/(decrease) in paid-in capital in 2021 mainly consist of equity contributions from Equinor ASA
 
to Equinor Ventures AS of USD
216 million and effect of sale of interest in Angara Oil LLC (Russia) of USD 166 million.
Distributions during 2022 consist of dividend from Equinor Energy AS of USD 17,550 million
 
related to 2022, change in group
contributions from group companies related to previous years of USD 451 million and dividends
 
related to 2021 from group companies
of USD 1,107 million.
Distributions during 2021 consist of group contribution from Equinor Energy AS of USD 7,245
 
million and Equinor Insurance AS of
USD 122 million related to 2021, change in group contributions from group companies related to
 
previous years of USD 327 million
and dividends related to 2020 from group companies of USD 1,007 million.
The acquisition costs for investments in subsidiaries and other equity accounted companies are USD 41,843 million
 
at 31 December
2022 and USD 36,287 million at 31 December 2021.
The following table shows significant subsidiaries and equity accounted companies directly held by Equinor
 
ASA at 31
December 2022:
Name
Ownershi
p share in
%
Country of
incorporation
Name
Ownershi
p share in
%
Country of
incorporation
Equinor Angola Block 15 AS
100
Norway
Equinor New Energy AS
100
Norway
Equinor Angola Block 17 AS
100
Norway
Equinor Nigeria AS
100
Norway
Equinor Angola Block 31 AS
100
Norway
Equinor Refining Norway AS
100
Norway
Equinor Apsheron AS
100
Norway
Equinor UK Ltd.
100
United Kingdom
Equinor BTC Finance AS
100
Norway
Equinor Ventures AS
100
Norway
Equinor Energy AS
100
Norway
Statholding AS
100
Norway
Equinor In Amenas AS
100
Norway
Equinor Metanol ANS
82
Norway
Equinor In Salah AS
100
Norway
Vestprosess DA
34
Norway
Equinor Insurance AS
100
Norway
For Investments, voting rights correspond to ownership.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
249
11 Financial assets and liabilities
Non-current receivables from subsidiaries and other equity
 
accounted companies
At 31 December
(in USD million)
2022
2021
Interest bearing receivables from subsidiaries and other
 
equity accounted companies
18,563
18,631
Non-interest bearing receivables from subsidiaries
566
124
Receivables from subsidiaries and other equity accounted
 
companies
19,129
18,755
Interest bearing receivables from subsidiaries and other equity accounted companies are mainly related
 
to Equinor Energy AS and
Equinor US Holdings Inc. The remaining amount on financial receivables interest bearing primarily relate to
 
long-term funding of other
subsidiaries.
Of the total interest bearing non-current receivables at 31 December 2022 USD 7,329 million is
 
due later than five years. USD 11,234
million is due within the next five years.
Current receivables from subsidiaries and other equity accounted companies include positive internal bank
 
balances of USD 332
million at 31 December 2022. The corresponding amount was USD 589 million at 31 December
 
2021.
Current financial investments
At 31 December
(in USD million)
2022
2021
Time deposits
12,350
7,009
Interest bearing securities
 
17,116
13,937
Financial investments
29,466
20,946
Interest bearing securities per debtor category
 
At 31 December
(in USD million)
2022
2021
Public Sector
2,982
4,029
Banks
9,280
4,581
Credit undertakings
1,048
3,911
Private Sector - Other
3,806
1,416
Total Interest bearing securities
17,116
13,937
Current financial investments in Equinor ASA are accounted for at amortised cost. For more
 
information about financial instruments by
category, see note 2 Financial risk management and measurement of financial instruments.
In 2022, interest bearing securities were split in the following currencies:
 
EUR (32%), USD (27%), NOK (21%), SEK (11%), DKK (6%),
GBP (2%) and AUD (1%). Time deposits were split in EUR (48%), NOK (39%) and USD (13%). In 2021, interest bearing
 
securities
were split in: SEK (31%), NOK (21%), EUR (21%), DKK (20%), USD (5%) GBP
 
(1%) and AUD (1%), while time deposits were split in:
EUR (36%), NOK (26%), USD (31%) and SEK (7%).
Current liabilities to subsidiaries and other equity accounted companies
Liabilities to subsidiaries and other equity accounted companies of USD 59,587 million at 31 December 2022
 
and USD 47,360 million
at 31 December 2021 mainly relates to Equinor group’s internal bank arrangements.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
250
 
Equinor, Annual Report on Form 20-F 2022
 
12 Inventories
At 31 December
(in USD million)
2022
2021
Crude oil
1,244
2,281
Petroleum products
505
379
Other
22
16
Inventories
1,771
2,676
The write-down of inventories from cost to net realisable value amounted to an expense
 
of USD 50 million and USD 22 million
 
in 2022
and 2021, respectively.
13 Trade and other receivables
At 31 December
(in USD million)
2022
2021
Trade receivables
10,624
12,017
Other receivables
3,566
1,447
Trade and other receivables
14,190
13,464
Other receivables mainly consist of collateral receivables.
14 Cash and cash equivalents
At 31 December
(in USD million)
2022
2021
Cash at banks
166
93
Time deposits
836
1,906
Money market funds
3,106
2,714
Interest bearing securities
3,263
4,725
Margin deposits
2,833
1,412
Cash and cash equivalents
10,204
10,850
Margin deposits consist of restricted cash pledged as collateral related to trading activities. Margin deposits are related
 
to certain
requirements set out by exchanges where Equinor ASA is trading. The terms and conditions
 
related to these requirements are
determined by the respective exchanges.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
251
15 Equity and shareholders
Change in equity
(in USD million)
2022
2021
Shareholders’ equity at 1 January
37,428
33,183
Net income/(loss)
27,546
8,162
Actuarial gain/(loss) defined benefit pension plans
356
111
Foreign currency translation effects
(2,389)
(645)
Dividend
(9,061)
(2,939)
Share buy-back
 
(3,380)
(429)
Share of OCI from equity accounted investments
424
0
Value of stock compensation plan
(10)
(15)
Total equity at 31 December
50,914
37,428
The accumulated foreign currency translation effect as of 31 December 2022 decreased total equity by USD 3,453 million.
 
At 31 December 2021, the corresponding effect was a decrease in total equity of USD 1,065 million. The foreign
 
currency translation
adjustments relate to currency translation effects from subsidiaries with functional currencies other than USD.
Common stock
Number of shares
NOK per value
At 31 December 2022
Common stock
Authorised and issued
3,175,470,159
2.50
7,938,675,397.50
Treasury shares/Share buy-back programme
(42,619,172)
2.50
(106,547,930.00)
Treasury shares/Share saving plan
(10,908,717)
2.50
(27,271,792.50)
Total outstanding shares
3,121,942,270
2.50
7,804,855,675.00
There is only one class of shares and all the shares have the same voting rights.
Share buy-back programme
In February 2022, Equinor launched a share buy-back programme for 2022 of up to USD 5,000 million, where
 
the first tranche of
around USD 1,000 million was finalised in March 2022. USD 330 million of the first
 
tranche was acquired in the open market. The
redemption of the proportionate share of 67% from the Norwegian State was approved by the annual
 
general meeting 11 May 2022
and settled in July 2022 as described below.
In May 2022, Equinor launched the second tranche of USD 1,333 million of the 2022
 
share buy-back programme of which USD 440
million was purchased in the open market. The acquisition of the second tranche in the
 
open market was finalised in July 2022.
In July 2022, Equinor increased the target level of share buy-back for 2022 from USD 5,000
 
million up to USD 6,000 million and
launched the third tranche of USD 1,833 million. USD 605 million was purchased in the
 
open market. The acquisition of the third
tranche in the open market was finalised in October 2022.
In October 2022, Equinor launched the fourth and final tranche of the share buy-back programme
 
for 2022 of USD 1,833 million. The
fourth tranche of USD 605 million (both acquired and remaining order) has been recognised as a
 
reduction in equity as treasury
shares due to an irrevocable agreement with the third party. As of 31 December 2022, USD 495
million of the fourth tranche has been
purchased in the open market, of which USD 475 million has been settled. The remaining order
 
of the fourth tranche is accrued for
and classified as Trade, other payables and provisions. The acquisition of the fourth tranche in the open market was finalised
 
in
January 2023.
After having finalised the 2021 share buy-back programme as well as the first tranche
 
of the 2022 share buy-back programme in the
market in the period 28 July 2021 to 25 March 2022, a proportionate share of 67% from the
 
Norwegian State was redeemed in
accordance with an agreement with the Ministry of Trade, Industry and Fisheries for the Norwegian State to maintain
 
their ownership
percentage in Equinor. The redemption was approved by the annual general meeting held on 11 May 2022. The shares were
 
252
 
Equinor, Annual Report on Form 20-F 2022
 
cancelled on 29 June 2022 and the liability of USD 1,399 million (NOK 13,496 million) to the
 
Norwegian State was settled on 20 July
2022.
For the second, third and fourth tranche of the share buy-back programme of 2022, USD 3,350 million of shares
 
from the Norwegian
State will, in accordance with an agreement with the Ministry of Trade, Industry and Fisheries, be redeemed at the annual
 
general
meeting in May 2023 in order for the Norwegian State to maintain its ownership share
 
of 67% in Equinor.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
253
Number of shares
2022
2021
Share buy-back programme at 1 January
13,460,292
-
Purchase
56,290,671
13,460,292
Cancellation
(27,131,791)
-
Share buy-back programme at 31 December
42,619,172
13,460,292
Employees' share saving plan
Number of shares
2022
2021
Share saving plan at 1 January
 
12,111,104
 
 
11,442,491
 
Purchase
 
2,127,172
 
 
3,412,994
 
Allocated to employees
 
(3,329,559)
 
(2,744,381)
Share saving plan at 31 December
 
10,908,717
 
 
12,111,104
 
In 2022 and 2021, treasury shares were purchased and allocated to employees participating in the
 
share saving plan for USD 72
million and USD 75 million, respectively. For further information,
 
see note 5 Share-based compensation.
For information regarding the 20 largest shareholders in Equinor ASA, please see Major shareholders
 
in section 5.3 Shareholder
information.
16 Finance debt
Non-current finance debt
At 31 December
(in USD million)
2022
2021
Unsecured bonds
26,612
27,568
Unsecured loans
76
87
Total
 
26,688
27,655
Non-current finance debt due within one year
2,547
250
Non-current finance debt
24,141
27,405
Weighted average interest rate (%)
3.29
3.33
Equinor ASA uses currency swaps to manage foreign currency exchange risk on its non-current financial liabilities.
 
For information
about the Equinor Group and Equinor ASA´s interest rate risk management, see note 4 Financial
 
risk and capital management in the
Consolidated financial statements and note 2 Financial risk management and measurement
 
of financial instruments in these financial
statements.
No new bonds were issued in 2022.
Substantially all unsecured bond and unsecured bank loan agreements contain provisions restricting future
 
pledging of assets to
secure borrowings without granting a similar secured status to the existing bond holders and lenders.
Out of Equinor ASA total outstanding unsecured bond portfolio, 38 bond agreements contain provisions
 
allowing Equinor to call the
debt prior to its final redemption at par or at certain specified premiums if there are changes to the Norwegian
 
tax laws. The carrying
amount of these agreements is USD 26,302 million at the 31 December 2022 closing currency exchange rate.
Short-term funding needs will normally be covered by the USD 5,000 million US Commercial paper
 
programme (CP) which is backed
by a revolving credit facility of USD 6,000 million, supported by 19 core banks, maturing in 2025.
 
The facility supports secure access
to funding, supported by the best available short-term rating. As at 31 December 2022, the facility
 
has not been drawn.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
254
 
Equinor, Annual Report on Form 20-F 2022
 
Non-current finance debt repayment profile
(in USD million)
Repayments
2024
2,399
2025
2,395
2026
2,183
2027
2,327
Thereafter
14,837
Total repayment of non-current finance debt
24,141
Current finance debt
At 31 December
(in USD million)
2022
2021
Collateral liabilities and other current financial liabilities
239
3,493
Non-current finance debt due within one year
2,547
250
Current finance debt
2,786
3,743
Weighted average interest rate (%)
2.13
0.68
Collateral liabilities and other current financial liabilities relate mainly to cash received
 
as security for a portion of Equinor ASA's credit
exposure and outstanding amounts on US Commercial paper (CP) programme. At 31 December 2022, USD
 
227 million was issued
on the CP programme. Corresponding at 31 December 2021 was USD 2,600 million.
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
255
17 Pensions
Equinor ASA is subject to the Mandatory Company Pensions Act, and the company's pension
 
scheme follows the requirements of the
Act. For a description of the pension scheme in Equinor ASA, reference is made to note 22 Pensions
 
in the Consolidated financial
statements.
Net pension cost
(in USD million)
2022
2021
Notional contribution plans
57
59
Defined benefit plans
186
214
Defined contribution plans
173
173
Total net pension cost
416
446
Employer contribution for pension cost is accrued for in current service cost and for the notional
 
and defined contribution plans.
Unpaid employer contribution is recognised as part of the pension liabilities.
 
In addition to the pension cost presented in the table above, financial items related to
 
defined benefit plans are included in the
Statement of income within Net financial items. Interest cost and changes in fair value of notional
 
contribution plans amounted to USD
33 million in 2022 and USD 211 million in 2021. Interest income of USD 109 million has been recognised in 2022, and USD 100
million in 2021.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
256
 
Equinor, Annual Report on Form 20-F 2022
 
Changes in pension liabilities and plan assets
 
during the year
(in USD million)
2022
2021
Pension liabilities at 1 January
8,938
8,748
Current service cost
181
207
Interest cost
98
232
Actuarial (gains)/losses and currency effects
(1,587)
(38)
Changes in notional contribution liability and other effects
62
62
Benefits paid
(251)
(274)
Pension liabilities at 31 December
7,441
8,938
Fair value of plan assets at 1 January
5,919
5,731
Interest income
109
100
Return on plan assets (excluding interest income)
(452)
287
Company contributions
100
112
Benefits paid
(115)
(115)
Foreign currency translation effects
(615)
(196)
Fair value of plan assets at 31 December
4,946
5,919
Net pension liability at 31 December
2,495
3,019
Represented by:
Asset recognised as non-current pension assets
 
(funded plan)
1,163
1,359
Liability recognised as non-current pension liabilities
 
(unfunded plans)
3,657
4,378
Pension liabilities specified by funded and unfunded
 
pension plans
7,441
8,938
Funded
3,784
4,560
Unfunded
3,657
4,378
Actuarial losses and gains recognised directly
 
in Other comprehensive income (OCI)
(in USD million)
2022
2021
Net actuarial (losses)/gains recognised in OCI
 
during the year
448
71
Foreign currency translation effects
261
75
Tax effects of actuarial (losses)/gains recognised in OCI
233
(35)
Recognised directly in OCI during the year, net of tax
942
111
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
257
Actuarial assumptions and sensitivity analysis
Actuarial assumptions, sensitivity analysis, portfolio weighting and information about pension assets
 
in Equinor Pension are presented
in note 22 Pensions in the Consolidated financial statements
 
for Equinor Group. The number of employees, including pensioners,
related to the main benefit plan in Equinor ASA is 8,697 at end of 31. December
 
2022 and 8,809 at end of 31. December 2021. In
addition, all employees are members of the early retirement plan (“AFP”) and different groups of employees are members
 
of other
unfunded plans.
Estimated company contributions to be made to Equinor Pension in 2023 is approximately USD
 
108 million.
18 Provisions and other liabilities
(in USD million)
Non-current portion at 31 December 2021
674
Current portion at 31 December 2021
46
Provisions and other liabilities at 31 December 2021
720
New or increased provisions and other liabilities
276
Change in estimates
1
Amounts charged against provisions and other liabilities
(1)
Reclassification and transfer
1,027
Foreign currency translation effects
1
Provisions and other liabilities at 31 December 2022
2,024
Non-current portion at 31 December 2022
1,841
Current portion at 31 December 2022
183
See also comments on provisions in note 21 Other commitments, contingent liabilities and contingent
 
assets
.
19 Trade, other payables and provisions
At 31 December
(in USD million)
2022
2021
Trade payables
1,331
2,665
Non-trade payables, accrued expenses and provisions
1,665
1,488
Payables to equity accounted associated companies
 
and other related parties
1,041
173
Trade, other payables and provisions
4,037
4,326
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
258
 
Equinor, Annual Report on Form 20-F 2022
 
20 Leases
Equinor ASA leases certain assets, notably transportation vessels, storage facilities and office buildings which
 
are used in operational
activity. Equinor ASA is mostly a lessee in its lease contracts and the leases serve operational purposes rather than as a tool for
financing.
Information related to lease payments and lease
 
liabilities
(in USD million)
2022
2021
Lease liabilities at 1 January
1,696
1,982
New leases, including remeasurements and cancellations
783
278
Gross lease payments
(645)
(575)
Lease interest
36
38
Lease repayments
 
(609)
(609)
(537)
(537)
Foreign currency translation effects
(74)
(27)
Lease liabilities at 31 December
1,797
1,696
Current lease liabilities
528
487
Non-current lease liabilities
1,269
1,209
Lease expenses not included in lease liabilities
(in USD million)
2022
2021
Short-term lease expenses
82
11
Payments related to short term leases are mainly related to transportation vessels. Variable lease expenses and lease expenses
related to leases of low value assets are not significant.
Equinor ASA recognised revenues of USD 199 million in 2022 and USD 149 million in
 
2021 related to lease costs recovered from
other Equinor group entities related to lease contracts being recognised gross by Equinor
 
ASA.
Commitments relating to lease contracts which had not yet commenced at year-end are included within
 
Other long-term commitments
in note 21 Other Commitments, contingent liabilities and contingent assets.
Non-current lease liabilities' maturity profile
At 31 December
(in USD million)
2022
2021
Year 2 and 3
659
510
Year 4 and 5
257
318
After 5 years
354
381
Total repayment of non-current lease liabilities
1,269
1,209
Undiscounted contractual lease payments for Equinor's lease liabilities are USD 573 million in
 
2023, USD 1,010 million within two to
five years and USD 394 million after five years.
The right of use assets are included within the line item Property, plant and equipment in the balance sheet. See also note 9 Property,
plant and equipment.
Equinor, Annual Report on Form 20-F 2022
 
259
21 Other commitments, contingent liabilities and contingent assets
Contractual commitments
Equinor ASA does not, as of 31 December 2022, have any contractual commitments related to exploration
 
activities.
Equinor ASA has entered into various long-term agreements for pipeline transportation as well
 
as terminal use, processing, storage
and entry/exit capacity commitments and commitments related to specific purchase agreements. The agreements ensure
 
the rights to
the capacity or volumes in question, but also impose on Equinor the obligation to pay for the agreed-upon
 
service or commodity,
irrespective of actual use. The contracts' terms vary with durations of up to 2060.
Take-or-pay contracts for the purchase of commodity quantities are only included in the table below if their contractually agreed
pricing is of a nature that will or may deviate from the obtainable market prices for the
 
commodity at the time of delivery.
Obligations payable by Equinor ASA to entities accounted for as associates and joint ventures
 
are included gross in the table below.
Obligations payable by Equinor ASA to entities accounted for as joint operations (for example
 
pipelines) and where consequently
Equinor’s share of assets, liabilities, income and expenses (capacity costs) are reflected on a line-by-line
 
basis in the Financial
statements, are included net (i.e. gross commitment less Equinor ASA’s ownership share).
The table below includes USD 867 million related to the non-lease components
 
of lease agreements reflected in the accounts
according to IFRS 16, as well as leases not yet commenced. See note 20 Leases for
 
information regarding lease related
commitments.
 
 
 
 
 
 
260
 
Equinor, Annual Report on Form 20-F 2022
 
Nominal minimum other long-term commitments at 31 December 2022:
(in USD million)
2023
1,230
2024
1,086
2025
1,126
2026
835
2027
729
Thereafter
4,631
Total other long-term commitments
9,637
Guarantees
Equinor ASA has provided parent company guarantees and also counter-guaranteed certain bank
 
guarantees to cover liabilities of
subsidiaries in countries of operations.
 
Equinor ASA has guaranteed for its proportionate portion of an associate’s long-term bank
debt, payment obligations under the contracts and some third-party obligations,
 
amounting to USD 265 million. The fair value and
book value of the guarantees
 
are immaterial.
Contingencies
Equinor ASA is the participant in certain entities ("DAs") in which the company has unlimited responsibility
 
for its proportionate share
of such entities' liabilities, if any, and participates in certain companies ("ANSs") in which the participants in addition have joint and
several liabilities. For further details, see note 10 Investments in subsidiaries and other equity accounted investments.
Resolved dispute with Norwegian tax authorities related to Equinor Service Center Belgium
 
N.V.
In 2020, Equinor received a decision from the Norwegian tax authorities related to the capital
 
structure of the subsidiary Equinor
Service Center Belgium N.V., concluding that the capital structure had to be based on the arm length’s principle, affecting the fiscal
years 2012 to 2016. Equinor received a claim of USD 182 million that was paid in 2021. During
 
2022, the tax authorities reversed their
decision and accepted Equinor’s initial position. The tax payment has been
 
reimbursed to Equinor, adjusted for changes in tax rates.
The adjustment, which has been recognised as tax expense in the Consolidated statement
 
of income in 2022, is considered
immaterial.
Other claims
During the normal course of its business, Equinor ASA is involved in legal proceedings,
 
and several other unresolved claims are
currently outstanding. The ultimate liability or asset in respect of such litigation and claims
 
cannot be determined at this time. Equinor
ASA has provided in its financial statements for probable liabilities related to litigation and claims
 
based on the company's best
judgment. Equinor ASA does not expect that its financial position, results of operations or cash flows
 
will be materially affected by the
resolution of these legal proceedings.
Provisions related to claims and disputes are reflected within note 18 Provisions and other liabilities.
Equinor, Annual Report on Form 20-F 2022
 
261
22 Related parties
Reference is made to note 27 Related parties in the Consolidated financial statements for information
 
regarding Equinor ASA’s related
parties. This includes information regarding related parties as a result of Equinor ASA’s ownership structure and also information
regarding transactions with the Norwegian State.
Transactions with group companies
Revenue transactions with related parties are presented in note 3 Revenues. Total intercompany revenues amounted to USD 2,768
million and USD 4,837 million in 2022 and 2021, respectively.
 
The major part of intercompany revenues is attributed to sales of crude
oil and sales of refined products to Equinor Marketing and Trading Inc, USD 2,541 million and USD 1,708 million in
 
2022 and 2021,
respectively and Equinor Refining Denmark A/S, no transactions and USD 2,523 million in 2022 and 2021,
 
respectively.
Equinor ASA sells natural gas and pipeline transport on a back-to-back basis to Equinor Energy
 
AS. Similarly, Equinor ASA enters
into certain financial contracts, also on a back-to-back basis with Equinor Energy AS. All of the risks related
 
to these transactions are
carried by Equinor Energy AS and the transactions are therefore not reflected in Equinor
 
ASA's financial statements.
Equinor ASA buys volumes from its subsidiaries and sells them into the market. Total purchases of goods from subsidiaries amounted
to USD 33,769 million and USD 24,473 million in 2022 and 2021, respectively. The major part of intercompany purchases of goods is
attributed to Equinor Energy AS, USD 21,266 million and USD 15,973 million in 2022
 
and 2021, respectively and Equinor US Holdings
Inc, USD 6,522 million and USD 4,551 million in 2022 and 2021, respectively.
In relation to its ordinary business operations, Equinor ASA has regular transactions with group companies in which
 
Equinor has
ownership interests. Equinor ASA makes purchases from group companies amounting to USD
 
187 million and USD 236 million in
2022 and 2021, respectively.
Expenses incurred by the company, such as personnel expenses, are accumulated in cost pools. Such expenses are allocated in part
on an hours incurred cost basis to Equinor Energy AS, to other group companies, and
 
to licences where Equinor Energy AS or other
group companies are operators. Costs allocated in this manner are not reflected in Equinor ASA's
 
financial statements. Expenses
allocated to group companies amounted to USD 10,520 million and USD 7,990 million in 2022
 
and 2021, respectively. The major part
of the allocation is related to Equinor Energy AS, USD 9,554 million, and USD 6,608 million in
 
2022 and 2021, respectively.
Other transactions
Reference is made to note 27 Related parties in the Consolidated financial statements for information
 
regarding Equinor ASAs
transactions with related parties based on ordinary business operations.
Current receivables and current liabilities from subsidiaries and other equity accounted companies are included
 
in note 11 Financial
assets and liabilities.
Related party transactions with management and management remunerations for 2022 are presented
 
in note 4 Salaries and
personnel expenses.
23 Subsequent events
Agreement to acquire Suncor Energy UK Limited
On 3 March 2023, Equinor entered into an agreement
 
to acquire 100% of Suncor Energy UK Limited
 
for a total consideration of USD 850
million before
adjustments
 
for working capital and net cash. USD 250
 
million is contingent on final investment decision on
 
the Rosebank field.
The transaction includes a non-operated interest
 
in the producing Buzzard oil field (29.89%) and
 
an additional interest in the operated
Rosebank development (40%). Closing of the transaction
 
is expected in the first half of 2023
 
subject to relevant regulatory approvals and will
be recognised in the E&P International segment.
262
 
Equinor, Annual Report on Form 20-F 2022
 
14 March 2023
THE BOARD OF DIRECTORS OF
 
EQUINOR ASA
/s/ JON ERIK REINHARDSEN
CHAIR
/s/ ANNE DRINKWATER
DEPUTY CHAIR
/s/ HAAKON BRUUN-HANSSEN
/s/ REBEKKA GLASSER HERLOFSEN
/s/ MICHAEL LEWIS
/s/ JONATHAN LEWIS
/s/ FINN BJØRN RUYTER
/s/ TOVE ANDERSEN
/s/ HILDE MØLLERSTAD
/s/ STIG LÆGREID
/s/ PER MARTIN LABRÅTEN
/s/ ANDERS OPEDAL
 
PRESIDENT AND
 
CEO
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
263
Additional
 
information
5.1
5.2
5.3
5.4
5.5
5.6
5.7
5.8
5.9
5.10
Board statement on corporate governance
 
Risk factors
Shareholder information
EU taxonomy for sustainable activities
Production per field
Additional sustainability information
Statements on this report incl. independent auditor reports
Use and reconciliation of non-GAAP financial measures
Terms
 
and abbreviations
Forward-looking statements
264
 
Equinor, Annual Report on Form 20-F 2022
 
Equinor, Annual Report on Form 20-F 2022
 
265
5.1 Board statement on corporate governance
This chapter provides a detailed overview of how Equinor follows the Norwegian Code of Practice
 
for Corporate Governance (the
Code of Practice). The Code of Practice covers 15 topics, and this board statement covers
 
each of these topics and describes
Equinor's adherence to the Code of Practice. Information that Equinor must provide in
 
accordance with the Norwegian Accounting Act
Section 3-3b is also included. The statement describes the foundation and principles for Equinor's
 
corporate governance structure.
The statement should be seen in context with information on corporate governance in section
 
1.8 Governance and risk management.
Further information can be found on www.equinor.com.
The deviations from the Code of Practice for corporate governance follow below.
6. General meetings
The Code of Practice recommends that the board of directors and chair of the nomination
 
committee be present at the general
meetings. Equinor has not deemed it necessary to require the presence of all members of the
 
board of directors. However, the chair of
the board, the chair of the nomination committee, the chair of the corporate assembly, external auditor, the CEO and other members
of management are always present at general meetings.
14. Take-overs
The Code of Practice recommends that the board establish guiding principles for how
 
it will act in the event of a take-over bid. The
board has not established such guidelines, due to Equinor's ownership structure. In the event of
 
a bid as discussed in section 14 of
the Code of Practice, the board of directors will, in addition to complying with relevant
 
legislation and regulations, seek to comply with
the recommendations in the Code of Practice. The board has no other explicit basic
 
principles or written guidelines for procedures to
be followed in the event of a take-over bid. The board of directors otherwise concurs with
 
what is stated in the Code of Practice
regarding this issue.
exhibit154p266i1 exhibit154p100i0 exhibit154p100i0 exhibit154p100i0 exhibit154p100i0
266
 
Equinor, Annual Report on Form 20-F 2022
 
 
Implementation and reporting
 
Equinor ASA is a Norwegian-registered public limited liability company with its primary listing
 
on Oslo Børs, and the foundation for the
Equinor group's governance structure is Norwegian law. American Depositary Receipts (ADR) representing ordinary shares are also
listed on the New York Stock Exchange (NYSE), and we are subject to the listing requirements of NYSE and the applicable reporting
requirements of the US Securities and Exchange Commission (SEC rules).
The following principles underline Equinor’s approach to corporate governance:
 
 
All shareholders will be treated equally.
 
Equinor will ensure that all shareholders have access to up-to-date, reliable and relevant information
 
about its activities.
 
Equinor will have a board of directors that is independent (as defined by Norwegian standards)
 
of the group's management. The
board focuses on preventing conflicts of interest between shareholders, the board of directors and
 
the company's management.
 
 
The board of directors will base its work on the principles for good corporate governance.
The governance and management system is further elaborated on our website at www.equinor.com/cg where shareholders and
stakeholders can explore any topic of interest in more detail.
Compliance with NYSE listing rules
Equinor's primary listing is on the Oslo Børs, and its ADRs are listed on the NYSE.
 
In addition, Equinor is a foreign private issuer
subject to the reporting requirements of the SEC rules.
ADRs represent the company's ordinary shares listed on the NYSE. While Equinor's corporate governance
 
practices follow the
requirements of Norwegian law, Equinor is also subject to the NYSE's listing rules.
As a foreign private issuer, Equinor is exempted from most of the NYSE corporate governance standards that domestic US
companies must comply with. However, Equinor is required to disclose any significant deviations from corporate governance practices
applicable to domestic US companies under the NYSE rules. This is disclosed in the annual report
 
on Form 20-F as filed to SEC and
published on www.equinor.com/reports.
2. Business
Equinor is an international energy company headquartered in Stavanger, Norway. The company has business operations in around
30 countries and approximately 22,000 employees worldwide. Equinor ASA is a public limited liability
 
company organised under the
laws of Norway and subject to the provisions of the Norwegian Public Limited Liability Companies
 
Act. The Norwegian State is the
largest shareholder in Equinor ASA, with a direct ownership interest of 67%.
 
Objective, strategies and risk profiles
Equinor’s objective is defined in the articles of association section 1 and is to
 
develop, produce and market various forms of energy
and derived products and services, as well as other business. The activities may also
 
be carried out through participation in or
cooperation with other companies. Equinor's current articles of association were adopted
 
at the annual general meeting of
shareholders on 11 May 2022 and are available at www.equinor.com/articlesofassociation .
Equinor’s purpose is turning natural resources into energy for people and progress for society. The board has approved a corporate
strategy to deliver on this purpose and the strategy has been translated into concrete objectives
 
and targets to align execution.
 
At Equinor, the way we deliver is as important as what we deliver. The Equinor Book, which addresses all Equinor employees, sets
the standards for behaviour, delivery and leadership.
Our Code of Conduct is further described in subsection 10. Risk management and internal
 
control in this chapter.
We also focus on managing the impacts of our activities on people, society and the environment, in line with corporate policies for
health, safety, security,
 
sustainability and climate, including human rights and ethics. These efforts and policies are further
 
described
in section 2.1 Always safe as well as section 2.3 Low carbon.
3. Equity and dividends
Shareholders' equity and capital structure
The board of directors considers the equity and capital structure of Equinor as at 31 December 2022 to
 
be satisfactory given the
company's requirements for financial robustness in relation to its expressed goals, strategy and
 
risk profile. Further information on the
Equinor, Annual Report on Form 20-F 2022
 
267
equity and capital structure can be found in sections 1.6 Capital and liquidity management, 2.2 High value
 
and the Consolidated
financial statements.
Any increase of the company’s share capital must be mandated by the general meeting. If
 
a mandate was to be granted to the board
of directors to increase the company's share capital, such mandate would be restricted
 
to a defined purpose. If the general meeting is
to consider mandates to the board of directors for the issue of shares for different purposes, each mandate would
 
be considered
separately by the general meeting.
Dividend policy
It is Equinor's ambition to grow the annual cash dividend, measured in USD per share,
 
in line with long-term underlying earnings.
Equinor announces dividends on a quarterly basis. The board approves first to third quarter interim
 
dividends based on an
authorisation from the general meeting, while the annual general meeting approves the fourth quarter (and
 
total annual) dividend
based on a proposal from the board. When deciding the interim dividends and recommending
 
the total annual dividend level, the
board will take into consideration expected cash flow, capital expenditure plans, financing requirements and appropriate financial
flexibility. In addition to cash dividends, Equinor might buy-back shares as part of the distribution of capital to the shareholders.
The shareholders at the annual general meeting may vote to reduce, but may not vote to increase, the fourth
 
quarter dividend
proposed by the board of directors.
Equinor declares dividends in USD. Dividends in NOK per share will be calculated and communicated
 
four business days after record
date for shareholders at Oslo Børs.
The dividend proposed by board of directors to the annual general meeting for the fourth quarter
 
is noted in section 2.2 High value –
Group Analysis.
Buy-back of own shares for subsequent annulment
In addition to cash dividend, Equinor may buy-back shares as part of the total distribution of capital to the
 
shareholders.
 
To buy-back
shares the board of directors will need an authorisation from the general meeting. The annual general
 
meeting authorised on 11 May
2022, the board of directors to acquire Equinor ASA shares in the market, on behalf
 
of the company, with a nominal value of up to
NOK 187,500,000. The board of directors is authorised to decide at what price within minimum
 
and maximum prices of NOK 50 and
NOK 1,000, respectively, and at what time such acquisition shall take place. Shares acquired pursuant to this authorisation can only
be used for annulment through a reduction of the company's share capital, pursuant to the Norwegian Public
 
Limited Liability
Companies Act section 12-1. It is also a precondition for the repurchase and the annulment of
 
shares that the Norwegian State's
ownership interest in Equinor ASA is not changed.
Purchase of own shares for use in the share savings plan
Since 2004, Equinor has had a share savings plan for its employees. The purpose of this plan is to strengthen
 
the business culture
and encourage loyalty through employees becoming part-owners of the company. The annual general meeting annually authorises
the board of directors to acquire Equinor ASA shares in the market in order to continue implementation
 
of the employees share
savings plan.
4. Equal treatment of shareholders and transactions with
 
close
associates
Equal treatment of all shareholders is a core governance principle in Equinor. Equinor has one class of shares, and each share
confers one vote at the general meeting. The articles of association contain no restrictions on voting
 
rights and all shares have equal
rights.
The Norwegian State as majority owner
The Norwegian State (the State) is the majority shareholder of Equinor and also holds
 
major investments in other Norwegian
companies. As of 31 December 2022, the State had an ownership interest in Equinor of
 
67% (excluding Folketrygdfondet’s
(Norwegian national insurance fund) ownership interest of 3.39%). The State is also a majority owner in other companies
 
or
enterprises that are under a common ownership structure and therefore meet the definition of a related party. Equinor may participate
in transactions with such companies or enterprises. All such transactions are always entered into on an
 
arm's length basis. The
State's ownership interest in Equinor is managed by the Ministry of Trade, Industry and Fisheries (MTIF) The State’s ownership
interests in related parties may be managed by the MTIF or other Ministries in
 
the Norwegian government, depending on the line of
business such related parties are engaged in.
Contact between the State as owner and Equinor takes in principle place in the same
 
manner as for other institutional investors,
however, with the difference that there are more frequent meetings with the MTIF. Topics
 
discussed includes Equinor's economic and
strategic development, sustainability and the State’s expectations regarding results and returns on investments.
 
Such meetings
268
 
Equinor, Annual Report on Form 20-F 2022
 
comply with Norwegian company and securities legislation, hereunder equal treatment of shareholders
 
and limitations for discussing
inside information.
 
In all matters in which the State acts in its capacity as shareholder, exchanges with the company are based on information
 
that is
available to all shareholders. If state participation is imperative and the government must seek
 
approval from the Norwegian
Parliament (Stortinget), it may be necessary to provide the Ministry with insider information. The
 
State will be subject to general rules
that apply to the handling of such information. Equinor ensures that, in any interaction between the
 
State and Equinor, a distinction is
drawn between the State's different roles.
The State has no appointed board members or members of the corporate assembly in Equinor. As majority shareholder, the State has
appointed a member of Equinor's nomination committee.
Sale of the State's oil and gas
Pursuant to Equinor's articles of association, Equinor markets and sells the State's share of oil
 
and gas production from the NCS
together with its own production. The State has a common ownership strategy aimed at maximising
 
the total value of its ownership
interests in Equinor and its own oil and gas interests. This strategy is incorporated in
 
the Owner’s Instruction, which obliges Equinor, in
its activities on the NCS, to emphasise these overall interests in decisions that may be
 
of significance to the implementation of the
sales arrangements.
The State-owned company Petoro AS handles commercial matters relating to the State's
 
direct involvement in petroleum activities on
the NCS and related activities and is responsible for overseeing that Equinor performs its tasks
 
in accordance with the Owner’s
Instruction.
Other transactions
In relation to its ordinary business operations such as pipeline transport, gas storage and processing of petroleum
 
products, Equinor
also has regular transactions with certain entities in which Equinor has ownership interests. Such
 
transactions are carried out on an
arm's length basis.
5. Freely negotiable shares
Equinor's primary listing is on Oslo Børs. ADRs are traded on the NYSE. Each Equinor
 
ADR represents one underlying ordinary
share.
The articles of association of Equinor do not include any form of restrictions on the ownership, negotiability
 
or voting related to its
shares and the ADRs.
6. General meeting of shareholders
The general meeting of shareholders is Equinor’s
 
supreme corporate body. It serves as a democratic and effective forum for interaction
between the company’s shareholders, board of directors and
 
management.
The next annual general meeting (AGM) is scheduled
 
for 10 May 2023. At Equinor's AGM on 11 May 2022, 77.87 % of the
 
share capital was
represented either by personal attendance, by proxy
 
or by advance voting.
 
Pursuant to Equinor’s articles of association,
 
the AGM must be held by the end of June each
 
year. Notice of the meeting and documents
relating to the AGM are published on Equinor's website
 
and notice is sent to all shareholders
 
with known addresses at least 21 days prior
 
to
the meeting. All shareholders who are registered in
 
the Norwegian Central Securities Depository (VPS)
 
will receive a notice to the AGM. Other
documents relating to Equinor's AGMs will be made
 
available on Equinor's website. A shareholder
 
may request that these documents be sent
to him/her.
Shareholders are entitled to have their proposals considered
 
at the AGM if the proposal has been
 
submitted in writing to the board of directors
in sufficient time to enable it to be included in the
 
notice of meeting, i.e. no later than 28
 
days before the meeting.
 
As described in the notice of the general
 
meeting, shareholders may vote in writing, including
 
through electronic communication, during a
specified period before the general meeting.
The AGM is normally opened and chaired by the
 
chair of the corporate assembly. If there is a dispute concerning individual
 
matters and the
chair of the corporate assembly belongs to one of
 
the disputing parties or is for some other reason
 
not perceived as being impartial, another
person will be appointed to chair the AGM. This is
 
in order to ensure impartiality in relation
 
to the matters to be considered.
 
The following matters are decided at the AGM:
exhibit154p269i1 exhibit154p100i0 exhibit154p269i1 exhibit154p269i1
 
Equinor, Annual Report on Form 20-F 2022
 
269
●
 
Approval of the board of directors' report, the
 
financial statements and any dividend proposed
 
by the board of directors and
recommended by the corporate assembly.
 
●
 
Election of the shareholders' representatives to the
 
corporate assembly and approval of the corporate
 
assembly's fees.
 
●
 
Election of the nomination committee and approval of
 
the nomination committee's fees.
 
●
 
Election of the external auditor and approval of
 
the auditor's fee.
 
●
 
Any other matters listed in the notice convening
 
the AGM.
The general meeting votes for each candidate nominated
 
for election to the company’s corporate assembly and
 
nomination committee.
 
All shares carry an equal right to vote at general
 
meetings. Resolutions at general meetings are normally
 
passed by simple majority. However,
Norwegian company law requires a qualified majority
 
for certain resolutions, including resolutions to waive
 
preferential rights in connection with
any share issue, approval of a merger or demerger, amendment of
 
the articles of association or authorisation
 
to increase or reduce the share
capital. Such matters require approval of at least
 
two-thirds of the aggregate number of votes
 
cast as well as two-thirds of the share capital
represented at the general meeting.
If shares are registered by a nominee in the
 
Norwegian Central Securities Depository (VPS),
 
cf. section 4-10 of the Norwegian Public Limited
Liability Companies Act, and the beneficial shareholder
 
wants to vote such shares, the beneficial shareholder
 
must re-register the shares in a
separate VPS account in such beneficial shareholder’s
 
own name prior to the general meeting.
 
If the holder can prove that such steps have
been taken and that the holder has a de facto
 
shareholder interest in the company, the company will allow the shareholder
 
to vote the shares.
Decisions regarding voting rights for shareholders and
 
proxy holders are made by the person
 
opening the meeting, whose decisions may be
reversed by the general meeting by simple majority
 
vote.
The minutes of the AGM are made available on
 
Equinor’s website immediately after the
 
AGM.
7. Nomination committee
Pursuant to Equinor's articles of association, the nomination committee shall consist of four members who
 
are shareholders or
representatives of shareholders. The duties of the nomination committee are set forth in the
 
articles of association, and the
instructions for the committee are adopted by the general meeting of shareholders.
 
The nomination committee seeks to ensure that the shareholders’ views are taken into consideration when
 
candidates to the
governing bodies of Equinor ASA are proposed. The nomination committee invites Equinor's
 
largest shareholders to propose
shareholder-elected candidates of the board of directors and the corporate assembly, as well as members of the nomination
committee. The shareholders are also invited to provide input to the nomination committee in respect
 
of the composition and
competence of Equinor's governing bodies considering Equinor's strategy and challenges and opportunities
 
going forward. The
deadline for providing input is normally set to early/mid-January so that such input may be taken into account
 
in the upcoming
nominations. In addition, all shareholders have an opportunity to submit proposals through
 
an electronic mailbox as described on
Equinor’s website. The results from an annual board evaluation are made available to
 
the nomination committee for the board
nomination process. Separate meetings are held between the nomination committee and
 
each board member, including employee-
elected board members. The chair of the board and the chief executive officer are invited, without
 
having the right to vote, to attend at
least one meeting of the nomination committee before it makes its final recommendations. The
 
committee regularly utilises external
expertise in its work and provides reasons for its recommendations of candidates.
When it comes to the subject of diversity and inclusion for the composition of the board of directors and
 
the corporate assembly, it is
stated in the instructions for the nomination committee section 3.5 that “Emphasis will also be given
 
to ensuring reasonable
representation in terms of gender and background, and to the independence of members
 
of the board of directors and corporate
assembly in relation to the company. The company’s guidelines on diversity and inclusion are described in section 2.1.4 Tackling
inequality – Diversity and inclusion.
The members of the nomination committee are elected by the annual general meeting. The
 
chair of the nomination committee and
one other member are elected from among the shareholder-elected members of the corporate assembly. Members of the nomination
committee are normally elected for a term of two years.
 
Equinor's nomination committee consists of the following members as of 31 December 2022
 
and are elected for the period up to the
annual general meeting in 2024:
 
Jarle Roth (chair), CEO of Umoe Group
9
 
(also chair of Equinor’s corporate assembly)
 
Jan Tore Føsund, Director General at the Ministry of Trade, Industry and Fisheries
 
 
Merete Hverven, CEO of Visma (also a member of Equinor’s corporate assembly)
 
Berit L. Henriksen, independent advisor
The board considers all members of the nomination committee to be independent of Equinor's management
 
and board of directors.
 
9
Roth was CEO of Umoe Group until 31 December
 
2022. As of 1 January 2023, Roth is an
 
independent advisor
270
 
Equinor, Annual Report on Form 20-F 2022
 
The nomination committee held 16 ordinary meetings in 2022.
The instructions for the nomination committee are available at www.equinor.com/nominationcommittee.
8. Corporate assembly,
 
board of directors and management
Corporate assembly
Pursuant to the Norwegian Public Limited Liability Companies Act, companies with more than 200
 
employees must elect a corporate
assembly unless otherwise agreed between the company and a majority of its employees.
The corporate assembly consists of 18 members, and the chair and deputy chair are elected by and among its members.
Members of the corporate assembly are normally elected for a term of two years. Members
 
of the board of directors and management
cannot be members of the corporate assembly, but they are entitled to attend and to speak at meetings unless the corporate
assembly decides otherwise in individual cases. Members of the corporate assembly do not have
 
service contracts with the company
or its subsidiaries providing for benefits upon termination of office.
An overview of the members and observers of the corporate assembly as of 31 December 2022
 
follows.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
271
Name
Occupation per 31.12.2022
Place of
residence
 
Year of
birth
Position
Family relations
to corporate
executive
committee,
board or
corporate
assembly
members
Share
ownership for
members as of
31 December
2022
Share
ownership
for
members
as of 14
March 2023
First
time
elected
Expiration
date of
current
term
Jarle Roth
CEO, Umoe Group
Bærum
1960
Chair,
Shareholder-
elected
No
500
500
2016
2024
Nils Bastiansen
Executive director of equities in
Folketrygdfondet
Oslo
1960
Deputy chair,
Shareholder-
elected
No
0
0
2016
2024
Finn Kinserdal
Associate professor,
Norwegian School of
Economics and Business
(NHH)
Bergen
1960
Shareholder-
elected
No
0
0
2018
2024
Kari Skeidsvoll Moe
EVP, Growth Renewable
Energy Aneo AS
Trondheim
1975
Shareholder-
elected
No
0
0
2018
2024
Kjerstin Fyllingen
CEO at Haraldsplass
Diakonale Sykehus AS
Paradis
1958
Shareholder-
elected
No
0
0
2020
2024
Kjerstin Rasmussen
Braathen
CEO of DNB Bank ASA
Oslo
1970
Shareholder-
elected
No
353
353
2020
2024
Mari Rege
Professor of Economics at the
UiS Business School at the
University of Stavanger
Stavanger
1974
Shareholder-
elected
No
0
0
2020
2024
Trond Straume
CEO of Volue ASA
Sandnes
1977
Shareholder-
elected
No
100
100
2020
2024
Martin Wien Fjell
Executive Vice President
Global Customer Support at
Kongsberg Maritime
Asker
1980
Shareholder-
elected
No
202
202
2022
2024
Merete Hverven
CEO of Visma
Oslo
1977
Shareholder-
elected
No
0
0
2022
2024
Helge Aasen
CEO of Elkem ASA
Kristiansand
1963
Shareholder-
elected
No
0
0
2022
2024
Liv B. Ulriksen
CEO of Sparebank 1 Nord-
Norge
Tromsø
1960
Shareholder-
elected
No
0
0
2022
2024
Peter B. Sabel
Union representative,
Tekna/NITO, Project Leader
 
Hafrsfjord
1968
Employee-
elected
No
0
0
2019
2023
Oddvar Karlsen
Union representative, Industri
Energi
Brattholmen
1957
Employee-
elected
No
418
618
2019
2023
Berit Søgnen Sandven
Union representative,
Tekna/NITO, Principal
Engineer Fiscal metering
Kalandseidet
1962
Employee-
elected
No
2,626
2,893
2019
2023
Terje Enes
Union representative, SAFE,
Discipl Resp Maint Mech
Stavanger
1958
Employee-
elected
No
3,096
3,341
2017
2023
Lars Olav Grøvik
Union representative, Tekna,
Advisor Petech
Bergen
1961
Employee-
elected
No
8,716
9,111
2017
2023
Per Helge Ødegård
Union representative, Lederne,
Discipl resp operation process
Porsgrunn
1963
Employee-
elected,
observer
No
496
289
1994
2023
Ingvild Berg
Martiniussen
Union representative,
Tekna/NITO, Principal
Researcher Production
Technology
Porsgrunn
1975
Employee-
elected,
observer
No
2,662
2,823
2021
2023
Anne Kristi Horneland
Union representative, Industri
Energi, employee
representative RIR
Hafrsfjord
1956
Employee-
elected,
observer
No
8,188
8,532
2006
2023
Total
27,155
28,762
272
 
Equinor, Annual Report on Form 20-F 2022
 
A total list of members and deputy members, as
 
well as the procedure for the work of the corporate
 
assembly, can be found at
www.equinor.com/corporateassembly.
 
The duties of the corporate assembly are defined
 
in section 6-37 of the Norwegian Public Limited
 
Liability Companies Act.
 
Equinor's corporate assembly held four ordinary
 
meetings in 2022. The chair of the board and
 
the CEO participated in all four meetings.
 
Board of directors
Pursuant to Equinor's articles of association,
 
the board of directors shall consist of between
 
9 and 11 members elected by the corporate
assembly. The chair and the deputy chair of the board are also elected by
 
the corporate assembly. At present, Equinor's board of directors
consists of 11 members. As required by Norwegian company law, the company's employees are
 
represented by three board members.
 
The employee-elected board members, but not
 
the shareholder-elected board members, have three
 
deputy members who attend board
meetings in the event an employee-elected member
 
of the board is unable to attend. The management
 
is not represented on the board of
directors. Members of the board are elected for
 
a term of up to two years, normally for one
 
year at a time. There are no board member
 
service
contracts that provide for benefits upon termination
 
of office.
The board considers its composition to be competent
 
with respect to the expertise, capacity and
 
diversity appropriate to attend to the
company's strategy, goals, main challenges, and the common interest of all
 
shareholders. The board members have experience
 
from oil, gas,
renewables, shipping, telecom, Norwegian defence
 
forces and environmental and sustainability work.
 
The board also deems its composition to
consist of individuals who are willing and able
 
to work as a team, resulting in an efficient
 
and collegiate board. At least one board member
qualifies as an "audit committee financial expert", as defined
 
in the SEC rules. The board has determined
 
that, in its judgment, all the
shareholder-elected on the board are considered independent.
 
In making its determinations of independence,
 
the board focuses inter alia on
there not being any conflicts of interest between
 
shareholders, the board of directors and the
 
company's management. Seven board members
are men, four board members are women and
 
three board members are non-Norwegians with residence
 
outside of Norway.
 
There were changes to the composition of the board
 
of directors after the election in the
 
corporate assembly meeting in June where Michael
D. Lewis was elected and replaced Jeroen
 
van der Veer with effect from 1 July 2022, and in the corporate assembly
 
meeting in November
where Haakon Bruun-Hanssen was elected and
 
replaced Bjørn Tore Godal with effect from 12 December 2022.
Equinor ASA has purchased and maintains a Directors
 
and Officers Liability Insurance on behalf of the
 
members of the board of directors and
the CEO. The insurance also covers any employee
 
acting in a managerial capacity and includes
 
controlled subsidiaries. The insurance policy
is issued by a reputable insurer with an appropriate
 
rating.
The board held eight ordinary board meetings and
 
four extraordinary meetings in 2022. Average attendance
 
at these board meetings was
99.17%.
 
Further information about the members
 
of the board and its committees is included in
 
chapter 1.8 Governance and risk management and
 
is
available on
 
www.equinor.com/board.
9. The work of the board of directors
The board is responsible for managing the Equinor group and for monitoring day-to-day management
 
and the group's business
activities. The board has established control systems to ensure that Equinor operates in compliance with
 
laws and regulations, with
the values as stated in the Equinor Book and the Code of Conduct, as well as in accordance
 
with the owners' expectations of good
corporate governance.
The board handles matters of major importance, or of an extraordinary nature, and may require
 
the management to present other
matters. An important task of the board is to appoint the chief executive officer (CEO) and to stipulate their job
 
instructions, and terms
and conditions of employment.
The board has adopted a generic annual plan for its work which is revised with regular intervals.
 
Recurring items on the board's
annual plan include safety, security, sustainability and climate, corporate strategy,
 
business plans, targets, quarterly and annual
results, annual reporting, ethics, management's monthly performance reporting, management compensation
 
issues, CEO and top
management leadership assessment and succession planning, project status review, people and organisation priorities, main risks
and an annual review of the board's governing documentation.
Climate-related upside and downside risks, and Equinor’s strategic response to these
 
are also discussed frequently by the board. In
2022, the board discussed climate change and the energy transition in all of the ordinary board meetings
 
either as integral parts of
strategy and investment discussions or as separate topics.
Equinor, Annual Report on Form 20-F 2022
 
273
An induction programme with key members of the management is arranged for new board members.
 
They receive an introduction to
Equinor’s business and relevant information about the company and the board’s work.
The board conducts an annual self-evaluation of its own work and competence, which is externally facilitated.
 
In the annual board
evaluation for 2022, climate change capabilities and knowledge were included as key components. The evaluation
 
report is discussed
in a board meeting and is made available to the nomination committee and also
 
discussed in a meeting between the chair of the
board and the nomination committee as input to the committee’s work.
Requirements for board members
The work of the board is based on rules of procedure that describe the board's responsibilities,
 
duties and administrative procedures.
They also describe the CEO’s duties vis-à-vis the board of directors.
The board's rules of procedure are available on our website at www.equinor.com/board.
The board of directors’ committees
Equinor’s board has established three committees: the audit committee; the compensation
 
and executive development committee;
and the safety, sustainability and ethics committee. The committees prepare items for consideration by the board and their authority is
limited to making recommendations.
Audit committee
The audit committee assists the board in exercising its oversight responsibilities in relation to:
●
 
The financial reporting process and the integrity of the financial statements.
●
 
The company’s internal control, internal audit and risk management systems and practices.
●
 
The recommendation of election of external auditor and qualifications, independence and oversight
 
of the work of the external
auditor.
●
 
Business integrity, including handling of complaints and reports.
●
 
Other duties as set out in the Norwegian Public Limited Liability Companies Act §
 
6-43 and Regulation 10A-3 of the US
Securities Exchange Act and applicable listing requirements.
The board of directors has determined that both Anne Drinkwater and Rebekka Glasser Herlofsen qualify
 
as "audit committee
financial expert", as defined in the SEC rules. The board of directors has also determined that the committee
 
has the qualifications
needed as defined in the Norwegian Public Limited Liability Companies Act. In addition, the
 
board of directors has concluded that
Anne Drinkwater, Rebekka Glasser Herlofsen, Jonathan Lewis and Finn Bjørn Ruyter are independent within the meaning of the
requirements in the Norwegian Public Limited Liability Companies Act and Rule 10A-3 under the Securities
 
Exchange Act.
The committee held six regular meetings in 2022, in addition to two deep dive sessions and attendance
 
was 96.67%.
For a more detailed description of the objective and duties of the committee, see the instructions available at
www.equinor.com/auditcommittee.
Compensation and executive development committee
The main responsibilities of the compensation and executive development committee are:
●
 
To make recommendations to the board in all matters relating to principles and the framework for executive rewards,
remuneration strategies and concepts, the CEO's contract and terms of employment, and leadership development, assessments
and succession planning.
●
 
To be informed about and advise the company's management in its work on Equinor's remuneration strategy for senior
executives and in drawing up appropriate remuneration policies for senior executives.
●
 
To review Equinor's remuneration policies in order to safeguard the owners' long-term interests.
The committee held six meetings in 2022 and attendance was 88.89%.
For a more detailed description of the objective and duties of the committee, see the instructions available at
www.equinor.com/compensationcommittee.
Safety, sustainability and ethics committee
The safety, sustainability and ethics committee assists the board in reviewing the practices and performance of the company primarily
in matters regarding safety, security, ethics, sustainability and climate. This includes quarterly reviews of the company’s risks related
to matters covered by the committee, practices and performance, including climate-related risks and performance.
The committee held four meetings and one extraordinary meeting in 2022 and attendance was
 
100%.
For a more detailed description of the objective and duties of the committee, see the instructions available at
www.equinor.com/ssecommittee.
274
 
Equinor, Annual Report on Form 20-F 2022
 
10. Risk management and internal control
Risk management
The board of directors oversees the company's internal control and overall risk management and assurance,
 
and through its audit
committee, reviews and monitors the effectiveness of the company's policies and practices in such
 
regard. On an ongoing basis, the
board and board audit committee discuss the company's enterprise risk management framework and three-lines
 
of control model and
learning from risk-adjusting actions and assurance activities. The board, board audit committee
 
and board safety, sustainability and
ethics committee, together, monitor and assess risks including legal, regulatory, financial, safety, security,
 
sustainability and climate-
related risks and the associated control measures put in place to manage them. Twice a year, the board receives and reviews an
assessment of all top enterprise risks, material emerging risks and risk-issues, and discusses the company's risk
 
profile.
Equinor manages risk to ensure that operations and other business activities are conducted in a safe and
 
secure manner, in
compliance with external and internal standards and requirements, so that unwanted incidents
 
are avoided, and maximum value is
created. The company's enterprise risk management framework endeavours to make risk considerations an integral
 
part of realising
its purpose and vision, and of driving day-to-day performance.
Through its three lines of control model, company-wide accountabilities for risk management,
 
and responsibilities for risk analysis,
monitoring, advising and assurance are defined across all relevant classes of risk, including business
 
integrity risks (fraud, sanctions,
competition, money laundering), safety/security/sustainability risks, financial/legal/regulatory risks, people risks
 
and political/public
affairs risks. Procedures and systems are in place to assess both potential financial impacts of risks on cash-flows and
 
potential non-
financial impacts of risks on people, the environment, physical assets, and ultimately, the company's reputation. Where necessary,
operational risks are insured by the company's captive insurance company, that operates in both Norwegian and international
insurance markets.
Further information about the risks and risk factors that the company's financial and operating
 
results are subject to are presented in
section 1.8 Governance and risk management and section 5.2 Risk factors.
Internal control over financial reporting
Equinor’s internal control over financial reporting is a process designed, under the
 
supervision of the chief executive officer and chief
financial officer, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of Equinor’s
financial statements in accordance with International Financial Reporting Standards.
 
Equinor’s internal control over financial reporting framework is based on COSO
 
2013 Internal Controls Integrated Framework. The
framework is governed by Equinor’s management system and implemented through a
 
top-down, risk-based approach across all
relevant functions and business areas within the company.
 
 
Equinor has established a global function (the ICoFR function), which is responsible for governing
 
Equinor’s internal control over
financial reporting on behalf of the CFO. The ICoFR function manages Equinor’s
 
annual process for internal control over financial
reporting and provides support and expertise to the organization to secure an effective and continuously improved internal
 
control
framework. The annual process includes formalized processes for scoping and risk assessment; control
 
design improvement and
maintenance; assurance of control design and operating effectiveness; deficiency management and evaluations; communications,
training and stakeholder reporting. Key assurance activities include independent verification testing of
 
controls; quarterly self-
assessments and management sign-offs; as well as internal audits conducted by Equinor’s corporate
 
audit function.
 
 
Equinor’s disclosure committee assists the CEO and CFO in assessing the status
 
of internal control over financial reporting on a
quarterly basis and reviewing Equinor’s public filings and disclosures, including its
 
consolidated financial statements and non-financial
disclosures, to ensure that the contents of Equinor’s results announcements, the Integrated annual
 
report, and the Annual report on
Form 20-F appropriately reflect reflect the non-financial and financial position and results of the company.
 
The board has delegated authority to the board audit committee to assist it in overseeing the effectiveness of Equinor’s
 
internal control
over financial reporting. The board audit committee reviews and discusses quarterly updates from
 
management on the status of key
financial reporting risks, control assurance activities and remediation of identified deficiencies, and internal
 
control improvement
initiatives. The board audit committee also reviews management’s evaluation of the effectiveness of Equinor’s internal
 
control over
financial reporting as required under Section 404 of the Sarbanes-Oxley Act
 
(included in the annual report on Form 20-F as filed with
SEC and published on www.equinor.com/reports)
 
and updates the board on the status of compliance and any significant issues that
warrant the attention of the board.
Code of Conduct
Ethics – Equinor’s approach
Equinor, Annual Report on Form 20-F 2022
 
275
Equinor believes that responsible and ethical behaviour is a necessary condition for a sustainable
 
business. Equinor’s Code of
Conduct is based on its values and reflects Equinor’s commitment to high ethical standards
 
in all its activities.
 
Our Code of Conduct
The Code of Conduct describes Equinor’s code of business practice and the requirements
 
for expected behaviour. The Code of
Conduct applies to Equinor’s board members, employees and hired personnel. It is divided
 
into five main categories: The Equinor
way, Respecting our people, Conducting our operations, Relating to our business partners and Communities and environment.
 
The Code of Conduct is approved by the board of directors.
 
Equinor seeks to work with others who share its commitment to ethics and compliance, and Equinor
 
manages its risks through in-
depth knowledge of suppliers, business partners and markets. Equinor expects its suppliers and
 
business partners to comply with
applicable laws, respect internationally recognised human rights and adhere to ethical standards which are
 
consistent with Equinor’s
ethical requirements when working for or together with Equinor. In joint ventures and entities where Equinor does not have control,
Equinor makes good faith efforts to encourage the adoption of ethics and anti-corruption policies and procedures that
 
are consistent
with its standards. Equinor will not tolerate any breaches of the Code of Conduct. Remedial measures
 
may include termination of
employment and reporting to relevant authorities.
 
More information about Equinor’s policies and requirements related to the Code
 
of Conduct and Equinor’s approach to integrity and
anti-corruption is available in section 2.2.4 Integrity and anti-corruption and on www.equinor.com/about-us/ethics-and-compliance.
11
. Remuneration to the board of directors and corporate assembly
Reference is made to section 1.8 Governance and risk management.
12.
 
Remuneration to the corporate executive committee
Reference is made to section 1.8 Governance and risk management.
13. Information and communications
Equinor has established guidelines for the company's reporting of financial and other information
 
and the purpose of these guidelines
is to ensure that timely and correct information about the company is made available
 
to our shareholders and society in general.
A financial calendar and shareholder information is published at www.equinor.com/calendar.
 
Investor relations is responsible for distributing and registering information in accordance with the
 
legislation and regulations that
apply where Equinor securities are listed. Investor relations reports directly to the chief financial
 
officer.
The company's quarterly presentations are broadcasted live on our website. Investor relations communicate with
 
present and potential
shareholders through presentations, one-to-one meetings, conferences, website, financial media, telephone,
 
mail and e-mail contact.
The related reports as well as other relevant information are available at www.equinor.com/investor where all information distributed to
the company's shareholders is published at the same time as it is sent.
14. Take-overs
The board of directors endorses the principles concerning equal treatment of all shareholders and Equinor's
 
articles of association do
not set limits on share acquisitions. Equinor has no defence mechanisms against take-over bids in its
 
articles of association, nor has it
implemented other measures that limit the opportunity to acquire shares in the company. The Norwegian State owns 67% of the
shares, and the marketability of these shares is subject to parliamentary decree.
15. External auditor
 
Our independent registered public accounting firm (external auditor) is independent in relation to
 
Equinor and is appointed by the
general meeting of shareholders. Our independent registered public accounting firm, Ernst & Young AS, has been engaged to provide
an audit in accordance with standards of the Public Company Accounting Oversight Board (United
 
States). Ernst & Young AS will also
issue a report in accordance with law, regulations, and auditing standards and practices generally accepted in Norway, including
276
 
Equinor, Annual Report on Form 20-F 2022
 
International Standards on Auditing (ISAs), which includes opinions on the Consolidated financial
 
statements and the parent company
financial statements of Equinor ASA. The reports are set out in section 5.7 Statements on this report
 
incl. independent auditor reports.
 
The external auditor's fee must be approved by the general meeting of shareholders.
Pursuant to the instructions for the board's audit committee approved by the board of directors,
 
the audit committee is responsible for
ensuring that the company is subject to an independent and effective external and internal audit. Every year, the external auditor
presents a plan to the audit committee for the execution of the external auditor's work.
 
The external auditor attends the meeting of the
board that deals with the preparation of the annual accounts.
 
The external auditor also participates in meetings of the audit committee. The audit committee
 
considers all reports from the external
auditor before they are considered by the board. The audit committee will meet as often as it
 
deems necessary, and normally five to
seven times a year. Both the board and the board’s audit committee hold meetings with the internal auditor and the external auditor on
a regular basis without the company’s management being present.
 
The audit committee evaluates and makes a recommendation to the board, the corporate
 
assembly and the general meeting of
shareholders regarding the choice of external auditor. The committee is responsible for ensuring that the external auditor meets
 
the
requirements in Norway and in the countries where Equinor is listed. The external auditor
 
is subject to the provisions of US securities
legislation, which stipulates that a responsible partner may not lead the engagement for more
 
than five consecutive years.
 
When evaluating the external auditor, emphasis is placed on the firm's qualifications, expertise, resources, objectivity, independence
and the auditor’s fee within the context of the standards required by applicable law, regulation and listing requirements.
The audit committee's policies and procedures for pre-approval
 
In its instructions for the audit committee, the board has delegated authority to the audit committee
 
to pre-approve assignments to be
performed by the external auditor. Within this pre-approval, the audit committee has issued further guidelines. The audit committee
has issued guidelines for the management's pre-approval of assignments to be performed by the
 
external
 
auditor.
All audit-related and other services provided by the external auditor must be pre-approved by the audit committee. Provided
 
that the
types of services proposed are permissible under SEC guidelines and Norwegian Auditors
 
Act requirements, pre-approval is usually
granted at a regular audit committee meeting. The chair of the audit committee has been authorised to
 
pre-approve services that are
in accordance with policies established by the audit committee that specify in detail the
 
types of services that qualify. It is a condition
that any services pre-approved in this manner are presented to the full audit committee at its next
 
meeting. Some pre-approvals can
therefore be granted by the chair of the audit committee if an urgent reply is deemed
 
necessary.
Remuneration of the external auditor in 2020 – 2022
 
In the annual Consolidated financial statements and in the parent company's financial statements,
 
the independent auditor's
remuneration is split between the audit fee and the fee for audit-related, tax and other services.
 
The breakdown between the audit fee
and the fee for audit related, tax and other services is presented to the annual general meeting
 
of shareholders.
 
Reference is made to the table in note 9 Auditor’s remuneration and Research
 
and development expenditures in the Consolidated
financial statements showing the aggregate fees related to professional services rendered by Equinor's
 
external auditor Ernst &
Young AS, for the fiscal years 2020, 2021, and 2022. All fees included in this table have been approved by the board's audit
committee.
Audit fee
 
is defined as the fee for standard audit work that must be performed every year in order
 
to issue an opinion on Equinor's
Consolidated financial statements, on Equinor's internal control over annual reporting and to issue
 
reports on the statutory financial
statements. It also includes other audit services, which are services that only the independent auditor
 
can reasonably provide, such as
the auditing of non-recurring transactions and the application of new accounting policies, audits of significant
 
and newly implemented
system controls and limited reviews of quarterly financial results.
Audit-related fees
 
include other assurance and related services provided by auditors, but not limited to those
 
that can only
reasonably be provided by the external auditor who signs the audit report, that are
 
reasonably related to the performance of the audit
or review of the company's financial statements, such as acquisition due diligence, audits of pension and benefit plans,
 
consultations
concerning financial accounting and reporting standards.
Tax and Other services fees
 
include services, if any, provided by the auditors within the framework of the Sarbanes-Oxley Act, i.e.,
certain agreed procedures.
Equinor, Annual Report on Form 20-F 2022
 
277
5.2 Risk factors
Strategic and commercial risks
Prices and markets
Fluctuating prices of oil and natural gas as well as exchange rates and general macroeconomic outlook
 
impact our financial
performance. Generally, Equinor does not have control over the factors that affect market development and prices.
Uncertainty in global and regional energy supply and demand means that Equinor's long-term
 
plans should take into consideration a
large outcome space for how global energy markets may develop. Examples of factors that
 
can affect supply and demand, and
consequently prices of oil, natural gas, electricity and other energy products include: global
 
and regional economic conditions, political
and regulatory developments, geopolitical tensions, actions of OPEC+ and other large energy suppliers, the social
 
and health situation
in any country or region, technological advances, availability of energy resources or access to energy
 
related acreages,
 
development
of supply chains and consumer preferences, including those related to climate issues.
Over the past years there has been significant volatility in energy prices, triggered by the supply
 
and demand impacts of the Covid-19
pandemic and the post-pandemic recovery, the European security situation,
 
including Russia’s invasion of Ukraine, and its effect on
global energy flows.
Energy prices and predominantly oil and natural gas prices are the primary drivers of Equinor’s
 
business results, financial condition
and liquidity, and ability to finance planned capital expenditures. A significant or prolonged period of low prices could lead to changes
in production, impairment of assets or reassessment of the viability of projects under development
 
and future business opportunities.
Increases in prices can lead to increased taxes, cost inflation or higher access costs for Equinor.
Fluctuating foreign exchange rates, especially between USD, EUR, GBP and NOK, can have
 
a significant impact on Equinor’s
operational and financial results. A large percentage of Equinor’s revenues and
 
cash receipts are denominated in or driven by USD,
sales of gas and refined products are mainly denominated in EUR and GBP, while a large portion of operating expenses, capital
expenditures and income taxes payable accrue in NOK. The majority of Equinor’s
 
long-term debt has USD exposure. See also the
description of market risk (including commodity price risk and currency risk) in Note 4 Financial
 
risk and capital management in the
Consolidated Financial Statements.
Hydrocarbon resource base and low carbon opportunities
Changes to Equinor’s hydrocarbon resource base estimates and ability to access
 
low carbon opportunities can impact future
production, revenues and expenditures as well as delivery of our strategy
.
Our estimates relating to current and future energy resources depend on many factors, variables
 
and assumptions that are beyond
Equinor’s control, and which may prove to be incorrect over time. The reliability
 
of resource estimates depends on the quality and
quantity of Equinor’s geological, technical and economic data together with extensive engineering
 
judgements. Substantial upward or
downward revisions in Equinor’s resources outlook may be required should additional
 
information become available after the initial
estimates were prepared. A substantial downward revision could potentially lead to impairments.
Equinor’s future oil and gas resource base depends on timely success to access, acquire
 
and develop attractive opportunities. If
unsuccessful, future production will decline and future revenue will be reduced.
 
Equinor’s access to resources is impacted by the
choices of governments and, outside of Norway, national oil and gas companies. Changes in fiscal terms and fluctuations in oil and
gas prices will have a direct impact on Equinor’s resource base. Proved oil and gas
 
reserves are estimated based on the US
Securities and Exchange Commission (SEC) requirements and may differ substantially from Equinor’s
 
view on expected reserves and
contingent resources.
Equinor’s ability to build material low carbon (both renewable and decarbonisation) business
 
portfolios depends on access to
attractive opportunities where the right commercial terms are key. Future conditions along with risks and uncertainties in power,
hydrogen and carbon markets as well as internal factors will influence our ability to achieve our
 
ambitions relating to renewable energy
resources and low carbon business.
Climate change and transition to a lower carbon economy
Policy, legal, regulatory,
 
market and technology developments, including stakeholder sentiment, related to the issue
 
of climate
change, can affect our business plans and financial performance.
Shifts in stakeholder focus between energy security, affordability and sustainability add uncertainty to delivery and outcomes
associated with Equinor’s strategy.
Stricter climate laws, regulations and policies as well as adverse litigation outcomes could adversely impact Equinor's
 
financial results
and outlook, including the value of its assets. This might be directly through regulatory towards energy
 
systems free of unabated fossil
278
 
Equinor, Annual Report on Form 20-F 2022
 
fuels,
 
changes in taxation, increased costs, access to opportunities, or indirectly through changes in
 
consumer behaviour or
technology developments.
Equinor expects greenhouse gas emission costs to increase from current levels and to have
 
a wider geographical range than today.
Equinor applies a default minimum carbon price in investment analysis starting at 58 USD
 
per tonne in 2022, increasing towards 100
USD per tonne by 2030. In countries where the actual or predicted carbon price is
 
higher than our default at any point in time, Equinor
applies the actual or expected cost, such as in Norway where both a CO2 tax and the EU
 
Emission Trading System (EU ETS) apply.
A higher carbon price provides incentive to reduce emissions and increase investment in new low
 
carbon solutions and technology.
Changing demand for renewable energy and low-carbon technologies, and innovation and technology
 
changes supporting their cost-
competitive development, represent both threats and opportunities for Equinor.
Market development and our ability to reduce costs and capitalise on technology improvements
 
are important but unpredictable risk
factors. Multiple factors in the energy transition contribute to uncertainty in future energy price assumptions,
 
and changes in investor
and societal sentiment can affect our access to capital markets, attractiveness for investors, and potentially restrict access to finance
or increase financing costs.
Strong competition for assets, changing levels of policy support, and different commercial/contractual models
 
may lead to diminishing
returns within the renewable and low carbon industries and hinder Equinor ambitions. These
 
investments may be exposed to interest
rate risk and inflation risk.
Equinor’s net zero strategy and climate related ambitions are responses to
 
challenges and opportunities in the energy transition.
There is no assurance that these ambitions will be achieved or that the method associated with
 
the ambitions will be accepted by all
stakeholders. Successful strategy execution depends on development of new technologies, new value chains, societal
 
shifts in
consumer demands, as well as firm leadership from policy makers. Should societal demands, technological
 
innovation and policy
support from governments not shift in parallel with Equinor’s pursuit of significant greenhouse
 
gas emission reductions and energy
transition investments, Equinor’s ability to meet its climate ambitions will be impaired.
International politics and geopolitical change
Political, economic, and social developments or instability in regions where Equinor has interests
 
and may seek future opportunities
could adversely affect Equinor’s business causing financial loss.
Political instability, civil strife, strikes, insurrections, acts of terrorism, acts of war, sanctions and trade disputes, public health situations
(including Covid-19), adverse and hostile actions against Equinor’s staff, its facilities, its transportation
 
systems and its digital
infrastructure (cyberattacks) may disrupt or curtail Equinor’s operations and business opportunities.
 
These may in turn lead to a
decline in production and otherwise adversely affect Equinor’s business, operations, results and financial
 
condition. Similarly,
Equinor’s response to such situations could lead to claims from partners and relevant stakeholders,
 
litigation, and litigation-related
costs.
In 2022, following Russia’s invasion of Ukraine, Equinor exited all projects in Russia and announced
 
an impairment of USD 1.08
billion on the balance sheet as of 31 March 2022. The European security situation will
 
continue to impact our business environment
volatility, uncertainty and complexity for the foreseeable future, including through impacts related to oil and gas supply and demand;
policy response, supply chains and security.
Digital and cyber security
Increasing digitization and reliance on information technology (IT) and operational technology (OT)
 
mean that failure to manage digital
and cyber threats could materially disrupt Equinor’s operations and financial condition.
Digital and cyber security threats such as unauthorized access or attacks by hackers, computer
 
viruses, breaches due to unauthorised
use, errors or malfeasance by employees or others who have gained access to Equinor
 
networks and systems, and insider threats to
our assets, could result in loss of production, loss of sensitive or private information, and
 
other safety and environmental losses. The
company could face associated regulatory actions, legal liability, reputational damage, and loss of revenue if any such threat
materializes.
Equinor could be required to spend significant financial and other resources to remedy the damage
 
caused by a security breach or to
repair or replace networks and information systems.
See also section 2.1.1 Safe and secure operations – Performance disclosure – Security incidents.
Project delivery and operations
Uncertainties in development projects and production operations in the Equinor portfolio could
 
prevent Equinor from realising profits
and cause substantial losses.
Oil and gas, renewable, low carbon and other projects or assets may be curtailed, delayed, cancelled
 
or suspended for many reasons.
Situations such as equipment shortages or failures, natural hazards, unexpected drilling conditions or reservoir
 
characteristics,
 
Equinor, Annual Report on Form 20-F 2022
 
279
irregularities in geological formations, challenging soil conditions, accidents, mechanical and technical
 
difficulties, power cost and
availability, protestor actions, health issues (including COVID-19), new technology implementation and quality issues might have
significant impact. The risk is higher in new and challenging areas such as deep waters
 
or other harsh environments, and in new
value chains.
Equinor’s portfolio of development projects includes a high number of major development-projects
 
as well as “first-off” projects (i.e.
involving new development concepts, operating regions, execution models, partners/contractors, value
 
chains and markets) that
increase portfolio complexity and potentially execution risk.
Equinor’s ability to commercially exploit energy resources and carbon products depends,
 
among other factors, on availability of
adequate capacity of transportation and/or transmission infrastructure to markets at a commercial
 
price. Equinor may be unsuccessful
in its efforts to secure commercially viable transportation, transmission and markets for all its potential production in a cost-efficient
manner or at all.
Joint arrangement and contractors
The actions of our partners, contractors and sub-contractors could result in legal liability and financial loss
 
for Equinor.
Many of Equinor’s activities are conducted through joint arrangements and with contractors
 
and sub-contractors which may limit
Equinor’s influence and control over the performance of such operations. If operators,
 
partners or contractors fail to fulfil their
responsibilities, Equinor can be exposed to financial, operational, safety, security and compliance risks as well as reputational risks
and risks related to ethics, integrity and sustainability.
Equinor is also exposed to enforcement actions by regulators or claimants in the event of an incident
 
in an operation where it does not
exercise operational control. Operators, partners and contractors may be unable or unwilling
 
to compensate Equinor against costs
incurred on their behalf or on behalf of the arrangement.
Competition and technological innovation
If competitors move faster or in other directions related to the development and deployment
 
of new technologies and products,
Equinor’s financial performance and ability to deliver on our strategy may be
 
adversely affected
.
Equinor could be adversely affected if we do not remain commercially and technologically competitive to efficiently develop and
operate an attractive portfolio of assets, to obtain access to new opportunities, and to keep pace
 
with deployment of new technologies
and products that can impact our transition to a broad energy company.
Equinor’s financial performance may be negatively impacted by competition from players
 
with stronger financial resources or with
increased agility and flexibility, and from an increasing number of companies applying new business models.
Ownership and action by the Norwegian State
The interests of Equinor’s majority shareholder, the Norwegian State, may not always be aligned with the interests of Equinor’s
 
other
shareholders and can impact Equinor’s strategy, ambitions and financial performance.
Failure of Equinor to deliver on broad societal, governmental and political expectations could impact
 
how the Norwegian State
exercises its ownership of the company and its decisions relating to the NCS.
The Norwegian State directly held 67% of Equinor's ordinary shares as of 31 December 2022
 
and has the power to influence the
outcome of any vote of shareholders, including amending its articles of association and electing
 
all non-employee members of the
corporate assembly. Factors influencing the voting of the Norwegian State could be different from the interests of Equinor’s other
shareholders.
The responsibility to exercise the Norwegian State’s ownership in Equinor is held by MTIF. MTIF’s exercise of ownership can be
subject to scrutiny by the Norwegian Parliament. In 2021, the Auditor-General expressed expectations with
 
respect to the ministry’s
follow-up of Equinor’s financial reporting, risk, profitability and return in Equinor’s
 
international portfolio.
 
The Norwegian State has resolved that its shares in Equinor and the SDFI’s interest in NCS licences must
 
be managed in accordance
with a coordinated ownership strategy for the Norwegian State’s oil and gas interests. Under this strategy, the Norwegian State has
required Equinor to market the Norwegian State’s oil and gas together with Equinor’s own
 
oil and gas as a single economic unit and to
take account of the Norwegian State’s interests in all decisions that may affect the marketing of these resources. If the Norwegian
State’s coordinated ownership strategy is not adequately implemented, then Equinor’s mandate to
 
sell the Norwegian State’s oil and
gas together with its own oil and gas is likely to be prejudiced which could have an
 
adverse effect on Equinor’s position in the markets
in which it operates
10
.
10
See also section 5.1 Board statement on corporate governance
 
for further details on State ownership and equal treatment
 
of shareholders and transactions with
close associates.
280
 
Equinor, Annual Report on Form 20-F 2022
 
Policies and legislation
Equinor’s operations in various countries are subject to dynamic legal and
 
regulatory factors that could impact our business plans and
financial performance.
 
Equinor operates in countries which lack well-functioning and reliable legal systems, where the enforcement
 
of contractual rights is
uncertain, and where the governmental, fiscal and regulatory regimes can change over time or
 
can be subject to unexpected or rapid
change. Such changes could constrain our plans, cause operational delays, increase costs of
 
regulatory compliance, increase
litigation risk, impact sale of our products, require us to divest or curtail operations, limit access to
 
new opportunities, and affect
provisions for pension, tax and legal liabilities.
Changes in the tax laws of the countries in which Equinor operates could have a material
 
adverse effect on liquidity and results of
operations.
Equinor's exploration and production activities undertaken together with national oil companies
 
are subject to a significant degree of
state control. In recent years, governments and national oil companies have in some regions
 
exercised greater authority and imposed
more stringent conditions on energy companies. Intervention by governments can take a
 
variety of forms, such as nationalization,
expropriation, cancellation, non-renewal, restriction or renegotiation of our interests, assets and related
 
rights. Equinor could be
subject to imposition of new contractual obligations, price and exchange controls, tax or royalty
 
increases, payment delays, and
currency and capital transfer restrictions.
Equinor's US operations use hydraulic fracturing, which is subject to a range of federal, state
 
and local laws. Various US states and
local governments have implemented, or are considering, changes to regulations or increased
 
regulatory oversight of hydraulic
fracturing that could adversely affect Equinor's US onshore business and the demand for its fracturing
 
services.
The ongoing maturation of the regulatory framework and permitting requirements for low carbon value-chains
 
in various countries can
impact financial outcomes from Equinor’s investment in related technologies, opportunities
 
and projects.
Equinor incurs, and expects to continue to incur, substantial capital-, operating-, maintenance-
 
and remediation costs relating to
compliance with increasingly complex laws, regulations and obligations related to the protection
 
of the environment and human health
and safety, as well as in response to concerns relating to climate change. Such occurrences could have a materially adverse effect on
Equinor’s operations and opportunities, liquidity and financial performance.
Finance
Equinor’s business is exposed to liquidity,
 
interest rate, equity and credit risks that could adversely affect the results of Equinor’s
operations, our financial position and ability to operate, as described in Note 4 to the Consolidated
 
Financial Statements.
Trading and commercial supply activities
Equinor’s trading and commercial supply activities in the physical markets
 
can lead to financial losses.
Equinor uses financial instruments such as futures, options, over-the-counter (OTC) forward contracts, market
 
swaps and contracts
for differences related to crude oil, petroleum products, natural gas and electricity to manage price differences and volatility. Trading
activities involve elements of forecasting, and Equinor bears the risk of market movements, the
 
risk of losses if prices develop contrary
to expectations, and the risk of default by counterparties.
There is a risk that an individual or group of traders acting for or on behalf of Equinor
 
could act outside of mandate and result in
financial loss, fines, or loss of licence to operate including permissions to trade.
 
Workforce and organisation
Equinor may not be able to secure the right level of workforce competence and capacity, or to leverage efficient organisational
operating models, to execute on strategy and operations.
Equinor depends on workforce capacity and competence to delivery on its strategy, including transition to a broad energy company.
Uncertainties related to the future of the oil and gas industry and the rate of growth of
 
new value chains, the need for new capabilities,
and increased competition for talent, pose a risk to securing the right level of workforce competence
 
and capacity through industry
cycles.
Further, company restructuring and Equinor’s changes to its operating model to meet the needs of the oil and gas,
 
renewable and low
carbon domains may not deliver on expectations.
Crisis management, business continuity and insurance coverage
Equinor's crisis management and business continuity systems may prove inadequate and disrupt our
 
business causing losses.
Equinor’s insurance coverage may not provide adequate protection from losses, with
 
a potential material adverse effect on Equinor’s
financial position.
Equinor, Annual Report on Form 20-F 2022
 
281
Our business could be severely affected if Equinor does not respond or is perceived not to have prepared, prevented,
 
responded, or
recovered in an effective and appropriate manner to a crisis or major incident. A crisis or disruption might
 
occur as a result of a
security or cyber security incident or if a risk described under “Security, safety and environmental risks” materialises.
Equinor maintains insurance cover that includes coverage for physical damage to its properties, third-party
 
liability, workers’
compensation and employers’ liability, general liability, sudden pollution, and other coverage. Equinor’s insurance coverage includes
deductibles that must be met prior to recovery and is subject to caps, exclusions, and limitations. There is no
 
assurance that such
coverage will adequately protect Equinor against liability from all potential consequences and damages as illustrated
 
by financial loss
for the group related to the fire at Hammerfest LNG in 2020.
The Equinor group retains parts of its insurable risks in a wholly owned captive insurance company, so insurance recovery outside of
the Equinor group may be limited.
Security,
 
safety and environmental risks
Health, safety and environmental factors
Equinor is exposed to a wide range of risk factors that could result in harm to people,
 
the environment, and our assets, as well as
cause significant losses through business interruption, increased costs, regulatory action, legal liability, and damage our licence to
operate.
Risk factors that could lead to impacts on health, safety and the environment include human performance,
 
operational failures, breach
of digital security, detrimental substances, subsurface conditions (including conditions related to hydraulic fracturing), technical
integrity failures, vessel collisions, natural disasters, adverse weather or climatic conditions, physical effects of climate change (see
section 2.2.2 Profitable Portfolio),
 
epidemics or pandemics (including COVID 19), breach of human rights, structural and
organizational changes and other occurrences. Continuation, resurgence or emergence of a pandemic, could
 
precipitate or aggravate
the other risk factors identified in this report and materially impact Equinor’s
 
operations and financial condition.
These risk factors could result in disruptions of our operations and could, among other things, lead to
 
blowouts, structural collapses,
loss of containment of hydrocarbons or other hazardous materials, fires, explosions and
 
water contamination that cause harm to
people, loss of life or environmental damage. All modes of transportation of hydrocarbons
 
are susceptible to a loss of containment of
hydrocarbons and other hazardous materials and represent a significant risk to people and the environment.
 
Equinor could also be
subject to civil and/or criminal liability and the possibility of incurring substantial costs, including for remediation
 
if any such health,
safety or environmental risk materialises.
It is not possible to guarantee that the management system or other policies and procedures will be able
 
to identify or mitigate all
aspects of health, safety and environmental risks or that all activities will be carried out in accordance
 
with these systems.
Security breaches
Equinor personnel, assets and operations may be subject to hostile acts that disrupt our operations and
 
cause harm to people or the
environment.
Terrorism, cyber-attacks, crime, armed conflict, civil unrest, maritime crime and illegal or unsafe activism can disrupt Equinor
operations and cause harm to our people, assets, or the environment.
 
Compliance and control risks
Supervisions, regulatory reviews and reporting
Supervision, review and sanctions for violations of laws and regulations at the supranational, national
 
and local level may lead to legal
liability, substantial fines, claims for damages, criminal sanctions and other sanctions for noncompliance, and reputational damage.
Laws and regulations include, among others, those relating to financial reporting, taxation,
 
bribery and corruption, securities and
commodities trading, fraud, competition and antitrust, safety and the environment, labour and employment
 
practices and data privacy
rules. The enactment of, or changes to, such laws and regulations could create compliance challenges
 
and increase the likelihood of
violation occurring.
Equinor is subject to supervision by the Norwegian Petroleum Supervisor (PSA), whose regulatory
 
authority covers the whole NCS
including offshore-wind as well as petroleum-related plants on land in Norway. Equinor may become subject to supervision or be
required to report to other regulators internationally, and such supervision could result in audit reports, orders and investigations.
Equinor is listed on Oslo Børs and New York Stock Exchange (NYSE) and is a reporting company under the rules and regulations of
the US Securities and Exchange Commission (the SEC). Equinor is required to comply with
 
the continuing obligations of relevant
regulatory authorities, and violation of these obligations may result in legal liability, the imposition of fines and other sanctions.
282
 
Equinor, Annual Report on Form 20-F 2022
 
Equinor is also subject to financial review from financial supervisory authorities such as the Norwegian
 
Financial Supervisory Authority
(FSA) and the SEC. Reviews performed by these authorities could result in changes to previously
 
published financial statements and
future accounting practices. In addition, failure of external reporting to report data accurately
 
and in compliance with applicable
standards could result in regulatory action, legal liability and damage to Equinor’s reputation.
Audits of financial statements could identify material weaknesses or deficiencies in Equinor’s
 
internal control over financial reporting
and cause loss of investor confidence that can potentially impact the share price.
Business integrity and ethical misconduct
Non-compliance with anti-corruption and bribery laws, anti-money laundering laws, competition and antitrust laws,
 
sanctions and trade
restrictions or other applicable laws, or failure to meet Equinor’s ethical requirements, could
 
expose Equinor to legal liability, lead to a
loss of business, loss of access to capital and damage our license to operate.
Equinor is subject to anti-corruption and bribery laws and anti-money laundering laws in multiple
 
jurisdictions, including the Norwegian
Penal code, the US Foreign Corrupt Practices Act and the UK Bribery Act. A violation of
 
such applicable laws could expose Equinor to
investigations from multiple authorities and may lead to criminal and/or civil liability with substantial
 
fines. Incidents of noncompliance
with applicable anti-corruption and bribery laws and regulations and the Equinor Code of Conduct
 
could be damaging to Equinor’s
reputation, competitive position, and shareholder value. Similarly, failure to uphold our Human Rights policy may damage our
reputation and social licence to operate.
Equinor has a diverse portfolio of projects worldwide and operates in markets and sectors impacted
 
by sanctions and international
trade restrictions. Sanctions and trade restrictions are complex, unpredictable and are often implemented on
 
short notice. While
Equinor remains committed to comply with sanctions and trade restrictions and takes steps
 
to ensure, to the extent possible,
compliance therewith, there can be no assurance that an Equinor entity, officer, director, employee, or agent is not in violation of such
sanctions and trade restrictions. Any such violation, even if minor in monetary terms, could result
 
in substantial civil and/or criminal
penalties and could materially adversely affect Equinor’s business and results of operations
 
or financial condition.
Equinor is subject to competition and antitrust laws in multiple jurisdictions, including the Norwegian Competition
 
Act, the Treaty of the
Functioning of the European Union and the Unites States’ Sherman Act, Clayton Act, HSR
 
Act and Federal Trade Commission Act.
 
A
violation of such laws could expose Equinor to investigations from multiple authorities and may lead to
 
criminal and/or civil liability with
substantial fines. Incidents of noncompliance with applicable competition and antitrust laws and the Equinor Code
 
of Conduct could be
damaging to Equinor’s reputation, competitive position, and shareholder value.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
283
5.3 Shareholder information
Equinor's share savings plan
Since 2004, Equinor has had a share savings plan for employees of the company. The purpose of this plan is to strengthen the
business culture and encourage loyalty through employees becoming part-owners of the company.
Through regular salary deductions, employees can invest up to 5% of their base salary in Equinor
 
shares. In addition, the
company contributes 20% of the total share investment made by employees in Norway, up to a maximum of NOK 1,500 per year
(approximately USD 150). This company contribution is a taxable employee benefit under 2022
 
Norwegian tax legislation. After a
lock-in period of two calendar years, one extra share will be awarded for each share purchased. Under current Norwegian
 
tax
legislation, the share award is a taxable employee benefit, with a value equal to the value of the
 
shares and taxed at the time of
the award.
The board of directors is authorised to acquire Equinor shares in the market on behalf of the company. The authorisation is valid
until 30 June 2023. This authorisation replaces the previous authorisation to acquire Equinor’s
 
own shares for implementation of
the share savings plan granted by the annual general meeting 11 May 2022. It is Equinor’s intention to renew this authorisation at
the annual general meeting on 10 May 2023.
Share buy-back
For the period 2013-2022, the board of directors has been authorised by the annual general meeting
 
of Equinor to repurchase
Equinor shares in the market for subsequent annulment. It is Equinor’s
 
intention to renew this authorisation at the annual general
meeting in May 2023.
The Annual General meeting on 11 May 2022 authorised the board of directors to acquire own shares in the market. The
authorisation is valid until the earlier of 30 June 2023 and the annual general meeting
 
in 2023. 56,222,
111
shares were
repurchased in the market as part of the 2022 Share buyback programme at USD 1.98 billion.
 
The share buy-back programme is
expected to be executed when Brent oil prices are in or above the range of 50-60 USD/bbl and Equinor’s
 
net debt ratio* stays
within the communicated ambition of 15-30% and this is supported by commodity prices.
Summary of shares repurchased
All shares repurchased have been purchased in the open market and pursuant to the authorisations
 
mentioned above. Also see
note 20 Shareholders’ equity and dividends to the Consolidated financial statements for more information.
Period in
which
shares
were
bought
back
Shares repurchased under AGM mandate for share-
based incentive plans
Shares repurchased under AGM mandate for
subsequent annulment
Number of
shares
repurchase
d
1)
Average
price per
share in
NOK
Total number
of shares
purchased as
part of
programme
Maximum
number of
shares that
may yet be
purchased
under the
programme
authorisation
Number of
shares
repurchased
2
)
Average
price per
share in
NOK
Total number
of shares
bought back
in the market
Maximum
number of
shares that
may yet be
bought back in
the market
under AGM
mandate
3)
Average
price per
share in
NOK
Total
number of
shares
repurchased
Jan-22
439,542
254.69
4 139 087
11 060 913
3,503,518
247.38
16,963,810
58,036,190
248.19
3,943,060
Feb-22
428,573
263.67
4 567 660
10 632 340
4,810,535
273.28
21,774,345
53,225,655
272.49
5,239,108
Mar-22
398,956
283.24
4,966,616
10,233,384
5,357,446
301.86
27,131,791
47,868,209
300.57
5,756,402
Apr-22
338,293
339.94
5,304,909
9,895,091
-
-
27,131,791
47,868,209
339.94
338,293
May-22
415,910
331.80
5,720,819
9,479,181
3,168,552
343.88
3,168,552
71,831,448
342.48
3,584,462
Jun-22
328,377
350.21
6,049,196
9,150,804
6,325,381
346.09
9,493,933
65,506,067
346.30
6,653,758
Jul-22
359,665
325.30
6,408,861
8,791,139
3,656,554
344.28
13,150,487
61,849,513
342.58
4,016,219
Aug-22
330,247
354.28
6,739,108
8,460,892
6,708,904
372.88
19,859,391
55,140,609
372.01
7,039,151
Sep-22
318,297
367.58
7,057,405
8,142,595
6,992,116
360.29
26,851,507
48,148,493
360.61
7,310,413
Oct-22
312,406
374.51
7,369,811
7,830,189
2,573,222
373.03
29,424,729
45,575,271
373.19
2,885,628
Nov-22
329,765
354.80
7,699,576
7,500,424
6,877,867
368.21
36,302,596
38,697,404
367.60
7,207,632
Dec-22
327,676
357.06
8,027,252
7,172,748
6,316,576
364.60
42,619,172
32,380,828
364.23
6,644,252
Jan-23
376,047
311.13
8,403,299
6,796,701
3,434,958
320.63
46,054,130
28,945,870
319.70
3,811,005
 
 
 
 
exhibit154p284i0 exhibit154p284i1
284
 
Equinor, Annual Report on Form 20-F 2022
 
Total
4,703,754
 
304.87
4)
59,725,629
 
286.89
4)
 
334.61
4)
64,429,383
1)
The shares repurchased from February 2022 to
 
January 2023 have been purchased in the
 
market under the buy-back program for
shares to be used in the share-based incentive plans
 
for employees announced 9 February 2022, with
 
duration from 15 February
2022 until 13 January 2023.
2)
The shares bought back in the market have
 
been bought under the following tranches:
The duration of the second tranche of the share buy-back
 
programme for 2021 announced 27 October
 
2021: 27 October 2021 to 31
January 2022 (ended 31 January 2022). Maximum
 
total consideration for the second tranche 2021: USD
 
330,000,000 (including the
State's share).
The duration of the first tranche of the share buy-back
 
programme for 2022 announced 9 February
 
2022: 10 February to 25 March
2022 (ended 25 March 2022). Maximum total consideration
 
for the first tranche 2022: USD 330,000,000
 
(including the State's share).
The duration of the second tranche of the share
 
buy-back programme for 2022 announced 4
 
May 2022: 16 May to 13 July 2022
(ended 13 July 2022). Maximum total consideration
 
for the second tranche 2022: USD 440,000,000
 
(including the State's share).
The duration of the third tranche of the share buy-back
 
programme for 2022 announced 27 July 2022:
 
28 July to 11 October 2022
(ended 11 October 2022). Maximum total consideration for the third tranche
 
2022: USD 604,890,000 (including the State's
 
share).
The duration of the fourth tranche of the share
 
buy-back programme for 2022 announced
 
28 October 2022: 31 October to 17
 
January
2023 (ended 17 January 2023). Maximum total
 
consideration for the fourth tranche 2022: USD 604,890,000
 
(including the State's
share).
3)
The maximum number of shares that may yet be bought
 
back in the market in January 2022 to April
 
2022 refers to the authorization
granted by the Annual General Meeting in May 2021.
 
The maximum number of shares that may yet be
 
bought back in the market in
May 2022 to January 2023 refers to the authorization
 
granted by the Annual General Meeting in May
 
2022.
4)
Weighted average price per share.
Major Shareholders
The Norwegian State is the largest shareholder in Equinor, with a direct ownership interest of 67%. Its ownership interest is managed
by the Norwegian Ministry of Trade, Industry and Fisheries.
 
As of 31 December 2022, the Norwegian State had a 67% direct ownership interest
 
in Equinor and a 3.39% indirect interest
through the National Insurance Fund (Folketrygdfondet), totalling 70.4%.
Equinor has one class of shares, and each share confers one vote at the general meeting. The
 
Norwegian State does not have
any voting rights that differ from the rights of other ordinary shareholders. Pursuant to the Norwegian Public Limited
 
Liability
Companies Act, a majority of at least two-thirds of the votes cast as well as of the votes represented
 
at a general meeting is
required to amend our articles of association. As long as the Norwegian State owns more
 
than one-third of our shares, it will be
able to prevent any amendments to our articles of association. Since the Norwegian State, acting
 
through the Norwegian Ministry
of Trade, Industry and Fisheries,
 
has in excess of two-thirds of the shares in the company, it has sole power to amend our articles
of association. In addition, as majority shareholder, the Norwegian State has the power to control any decision at general
meetings of our shareholders that requires a majority vote, including the election of the majority
 
of the corporate assembly, which
has the power to elect our board of directors and approve the dividend proposed by the board of
 
directors.
The Norwegian State endorses the principles set out in "The Norwegian Code of Practice for Corporate
 
Governance", and it has
stated that it expects companies in which the State has ownership interests to adhere
 
to the code. The principle of ensuring equal
 
 
 
 
 
 
 
exhibit154p285i0
Equinor, Annual Report on Form 20-F 2022
 
285
treatment of different groups of shareholders is a key element in the State's own guidelines. In companies in which
 
the State is a
shareholder together with others, the State wishes to exercise the same rights and obligations as
 
any other shareholder and not
act in a manner that has a detrimental effect on the rights or financial interests of other shareholders. In addition
 
to the principle of
equal treatment of shareholders, emphasis is also placed on transparency in relation to the State's
 
ownership and on the general
meeting being the correct arena for owner decisions and formal resolutions.
Shareholders at December 2022
Number of Shares
Ownership in %
1
Government of Norway
2 127 565 006
67.00%
2
Folketrygdfondet
107 556 485
3.39%
3
BlackRock Institutional Trust Company, N.A.
1)
33 594 128
1.06%
4
The Vanguard Group, Inc.
1)
33 044 872
1.04%
5
DNB Asset Management AS
20 502 622
0.65%
6
T. Rowe Price Associates, Inc
1)
20 088 971
0.63%
7
Arrowstreet Capital, Limited Partnership
1)
18 970 039
0.60%
8
KLP Fondsforvaltning AS
18 021 894
0.57%
9
Storebrand Kapitalforvaltning AS
17 981 425
0.57%
10
Schroder Investment Management Ltd. (SIM)
1)
16 093 884
0.51%
11
RBC Global Asset Management (UK) Limited
1)
15 220 382
0.48%
12
Capital World Investors
1)
14 876 437
0.47%
13
Acadian Asset Management LLC
1)
13 125 439
0.41%
14
Fidelity Management & Research Company LLC
1)
12 509 728
0.39%
15
Nuveen LLC
1)
12 472 468
0.39%
16
State Street Global Advisors (US)
1)
12 194 750
0.38%
17
Marathon-London
11 455 171
0.36%
18
BlackRock Advisors (UK) Limited
1)
9 675 279
0.30%
19
SAFE Investment Company Limited
9 575 483
0.30%
20
Amundi Asset Management, SAS
1)
8 982 794
0.28%
1) Shareholder with US registered address
Source: Data collected by third party, authorised by Equinor, December 2022.
5.4 EU Taxonomy
 
for sustainable activities
Equinor has implemented the EU Taxonomy disclosure in accordance with EU Regulation 2020/852 and the Delegated Acts related to
Article 8 (information to be disclosed), 10 (climate change mitigation) and 11 (climate change adaption) that require the disclosure
about the environmental performance of the company’s assets and economic activities. The regulation establishes
 
the criteria to
determine whether an economic activity qualifies as environmentally sustainable and specifies quantitative
 
economic performance
indicators to disclose the degree of sustainability. The activities defined to be eligible under the EU Taxonomy regulations are listed
within the delegated acts and continue to evolve with review. The regulation has been enacted in Norwegian legislation with effect for
2023. Equinor’s reporting is thus a voluntary reporting.
An activity is “Taxonomy-eligible” if it is described in the regulation, irrespective of whether it complies with the technical screening
criteria. An activity is “Taxonomy-aligned” if it contributes substantially to one or more environmental objectives, does no significant
harm to any of the other objectives, and is carried out in compliance with minimum safeguards.
 
286
 
Equinor, Annual Report on Form 20-F 2022
 
In order to achieve its ambition to become a net-zero emissions company by 2050, Equinor undertakes emission
 
reducing activities
that are supporting the continued operating of oil and gas production. While these help Equinor
 
towards its ambition, some of these
activities (notably onshore electrification of offshore assets) are not eligible per the EU Taxonomy regulations and therefore are not
visible in our eligibility scores.
 
EU Taxonomy regulations exclude contributions to the KPI’s from activities in equity accounted investments. A large proportion of
Equinor’s environmentally sustainable activities are conducted through equity accounted investments
 
and therefore are not evaluated
in the mandatory key performance indicator (KPI) disclosure. To provide more holistic information of the environmentally sustainability
activities of Equinor, a voluntary disclosure including the
capex eligibility KPI for equity accounted investments has been included in
the section on voluntary KPI’s
.
Equinor performed EU Taxonomy alignment evaluations in 2022 for the significant activities in its portfolio of eligible activities. The
testing covered both producing assets and assets under development.
The alignment testing in 2022 covered current investments related to electricity generation
 
from wind power and photovoltaic
technology. We also acquired some investments related to storage of electricity in the year which we have not yet been able to
complete full alignment testing, but for which we expect positive contributions to our alignment KPI’s in
 
future years.
All tested eligible activities passed the substantial contribution criteria. When assessing compliance with
 
the Do No Significant Harm
criteria the following interpretations and judgments were applied:
 
●
 
Climate change adaption - relevant climate related hazards have been assessed based
 
on a risk assessment.
 
●
 
Circular economy - durability and recyclability have been assessed where feasible.
 
●
 
For DNSH criteria that reflect legal requirements under EU regulations, the technical
 
screening criteria are considered met
when the operations are conducted within normal, lawful operations, comply with emission permits, environmental
 
impact
assessments have been performed and necessary action have been taken when required.
Based on the alignment testing performed the tested assets and associated activities are aligned
 
with the technical screening criteria
by year-end 2022.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
exhibit154p287i0
Equinor, Annual Report on Form 20-F 2022
 
287
Key performance indicators
2022
(in USD million)
Turnover
Capex
Opex
Aligned Eligible Activity
0
 
157
 
0
 
Total Eligible Activity
0
 
245
 
0
 
Non Eligible
150,262
 
9,376
 
1,555
 
Total
150,262
 
9,621
 
1,555
 
Aligned Eligible Activity
0%
2%
0%
Total Eligible Activity
0%
3%
0%
Non Eligible
100%
97%
100%
2021
Turnover
Capex
Opex
Eligible
1)
0%
2%
0%
1) Alignment was not assessed for 2021
Environmentally sustainable economic activities
In order for an economic activity to qualify as environmentally sustainable under the EU Taxonomy it is required to substantially
contribute to one or more of the following environmental objectives:
Climate Change mitigation (i)
 
The process of holding the increase in the global average temperature to well below
 
2°C and pursuing efforts to limit it to 1.5°C above
pre-industrial levels, as laid down in the Paris Agreement
Climate Change adaption (i)
The process of adjustment to actual and expected climate change and its impacts.
Sustainable use and protection of water and marine resource (ii)
 
Achieving the good status of bodies of water, including bodies of surface water, groundwater, and marine waters or to preventing the
deterioration of bodies of water that already have good status,
 
Transition to a circular economy (ii)
An economic system whereby the value of products, materials and other resources in the economy
 
is maintained for as long as
 
 
 
 
exhibit154p288i0
288
 
Equinor, Annual Report on Form 20-F 2022
 
possible, enhancing their efficient use in production and consumption. Minimising waste and the release
 
of hazardous substances at
all stages of their life cycle.
Pollution prevention and control (ii)
Preventing or, where that is not practicable, reducing pollutant emissions into air, water or land, other than greenhouse gasses.
Improving levels of air, water or soil quality in the areas in which the economic activity takes place whilst minimising any adverse
impact on, human health and the environment or the risk thereof; and preventing or minimising
 
any adverse impact on human health
and the environment of the production, use or disposal of chemicals
Protection and restoration of biodiversity and ecosystems (ii)
 
Protecting, conserving or restoring biodiversity or to achieving the good condition of ecosystems,
 
or to protecting ecosystems that are
already in good condition
(i) Delegated Act published and included in the 2022 reporting
(ii) Related Delegated Act expected to be phased in by the EU from 2023 and included
 
from the 2024 reporting.
EU taxonomy assessment for Equinor specific activity
Double counting of the relevant amounts of turnover and expenditure across the reporting has been
 
avoided based on the eligible
economic activities included in the KPIs are independent activities.
Mandatory KPIs
Basis for preparation
The key performance indicators consist of the portion of taxonomy-eligible and aligned economic
 
activities in the total turnover, capital
and operational expenditures in accordance with the Taxonomy regulation.
 
The mandatory KPI’s for 2022 consist of the portion of taxonomy-eligible and aligned activities in the total
 
turnover, capital (capex)
and operational (opex) expenditures as included in the Consolidated financial statements and
 
balance sheet prepared in accordance
with IFRS, and in accordance with the principles described in the appendix below.
Eligible activities
Eligible activities included in the mandatory KPIs comprises:
●
 
4.1 Electricity generation from photovoltaic technology
●
 
4.3 Electricity generation from wind power
●
 
4.10 Storage of electricity
 
4.1 Electricity generation using solar photovoltaic technology
The activity covers construction or operation of electricity generation facilities that produce electricity using
 
solar photovoltaic (PV).
The activity consists of developing onshore renewables solar projects in Poland.
 
4.3 Electricity generation from wind power
 
The main wind power activity included in the mandatory KPI is the development of the
 
Hywind/Tampen floating wind farm intended to
provide electricity for the Snorre and Gullfaks offshore oil and gas fields. Electricity generation from wind
 
power contributes directly to
the environmental objectives and is not a transitional or enabling economic activity subject to
 
the assessment of the lock-in effects,
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
289
even if it would provide for continuing operation of oil and gas installations. The eligibility
 
assessment of this asset has been matured
and reassessed from 2021 and based on the regulator’s clarification of definition of economic
 
activities the Hywind/Tampen project
has been included in eligible activities in 2022.
4.10 Storage of electricity.
The activity consists of storing electricity from renewable sources to return to the grid at a later time.
 
 
In addition, Equinor are engaged in several Hydrogen development activities and Underground permanent
 
geological storage of CO
2
activities which are undergoing continued maturation.
 
These activities have no significant effect on the KPIs for 2022.
 
At the Mongstad refinery biofuel raw material is bought and processed together with other fossil
 
raw materials. Based on the low
proportion of biofuel in the final product blend Equinor has not included this in the eligible
 
activities.
Equinor’s material eligible economic activities in 2022 primarily relate to the environmental
 
objective “climate change mitigation”, and
not the climate change adaptation objective.
 
Technical screening assessment
Equinor has carried out the assessment process as described in the appendix below. The technical screening assessment has been
conducted based on materiality and covers the activities electricity generation from wind power and
 
electricity generation using solar
photovoltaic technology. The energy storage activities were acquired late in 2022 and will be subject technical screening assessment
in 2023. Based on the conditions with regards to interpretation and fulfilment of the criteria described above, no material
 
issues related
to the screening assessment have been identified by year-end 2022.
Substantial contribution
By definition, electricity generation from wind power and solar makes a substantial contribution
 
to climate change mitigation within the
EU taxonomy.
 
Does no significant harm assessment
Electricity generation from wind power contributes substantially to an environmental objective if it
 
does no significant harm to climate
change adaption, water and marine resources, circular economy and biodiversity. Electricity generation using solar photovoltaic
technology contributes substantially to an environmental objective if it does no significant harm to
 
climate change adaption, circular
economy and biodiversity.
Results and basis for conclusion
Climate change adaption
For 2022, Equinor has conducted a climate risk and vulnerability mapping of the eligible assets covering
 
the climate related hazards
we consider most relevant. The assessment has been conducted for the representative Concentration Pathway
 
(RCP) scenario’s RCP
2.6, RCP 4.5 and RCP 8.5 including 10, 30 and 50 years climate projections. Equinor installations
 
are designed with margins to
tolerate a range of meteorological conditions. No significant changes in the risk perils
 
based on the scenarios for the tested assets
were detected.
 
Water and marine resources
In case of construction of offshore wind, the activity must not hamper the achievement of good environmental
 
status in accordance
with EU regulations. Appropriate measures in accordance with the relevant criteria and methodological
 
standards are required to
prevent or mitigate impacts related to noise and energy.
 
Environmental impact assessment has been conducted and the activity are conducted within normal lawful operations.
 
Circular economy
For the tested assets, availability of and, where feasible, use of equipment and components
 
of high durability and recyclability which
are easy to dismantle and refurbish have been assessed. The durability of the components were
 
deemed to be in accordance with
requirements at the time of the investments.
 
Recycling of the components in the wind turbines blades and solar panels is currently not feasible. However, as technology is evolving
the reuse and refurbishment of components is expected to increase.
 
Based on the requirement at the time of investments and current feasibility the tested activities are
 
deemed to be aligned with the
screening criteria.
 
Biodiversity
For electricity generation using solar photovoltaic technology and electricity generation from wind
 
power an environmental impact
assessment (EIA) or screening in accordance with the EU requirements are required to document that
 
the activity does no significant
harm to any of the other environmental objectives. Where an EIA has been carried out, the
 
required mitigation and compensation
measures for protecting the environment must be implemented.
 
 
 
 
 
 
 
 
 
290
 
Equinor, Annual Report on Form 20-F 2022
 
For sites/operations located in or near biodiversity-sensitive areas, an appropriate assessment, where applicable,
 
must have been
conducted in accordance with specific EU directives and based on its conclusions the
 
necessary mitigation measures implemented.
In case of construction of offshore wind, appropriate measures in accordance with the criteria and methodological
 
standards set out in
accordance with specific EU directives, must be taken to prevent or mitigate impacts relate to
 
biodiversity and seabed integrity.
Environmental impact assessment has been conducted and the activities are conducted within normal lawful
 
operations.
 
Minimum safeguards
Compliance with the requirements have been determined by assessing the criteria against the four
 
topics:
 
●
Human rights, including workers’ rights
●
Bribery/Corruption
●
Taxation
●
Fair competition
 
Equinor minimum safeguards procedures are based on the United Nations Guiding principles
 
on Business and Human Rights
(UNGPs). Mitigating actions are initiated to respond to any identified risks.
 
Voluntary KPIs
To provide further information on our environmentally sustainability activity Equinor has included a voluntary disclosure of the capex
KPI for 2022 including contributions from equity accounted investments. These activities are conducted
 
through both operated and
non-operated joint ventures mainly outside the EU jurisdiction. The main part of the activities
 
is related to development projects.
Based on the nature of the activities the R&D and maintenance related expenses are limited. Hence
 
Opex is not included in the
voluntary KPIs in 2022. The KPIs has been calculated on a pro rata basis corresponding to
 
Equinor’s share of capex in the joint
ventures. The KPI numerator includes the eligible activities, and the denominator includes both
 
eligible and non-eligible activity.
 
Equinor has limited its voluntary capex KPI to eligible activities. Extensive documentation requirements and
 
limited data availability,
especially related to non-operated joint ventures outside the EU jurisdiction, has not made
 
it practical to complete alignment testing
over the majority of the portfolio activities which are equity accounted for 2022. The technical
 
screening process for the non-operated
assets will be conducted in coordination with the operator of the equity accounted assets.
 
Eligible activities included in the voluntary KPI
Eligible activities included in the voluntary KPIs comprises:
●
 
4.1 Electricity generation from photovoltaic technology
●
 
4.3 Electricity generation from wind power
●
 
5.12 Underground permanent geological storage of CO2
●
 
4.29 Electricity generation from fossil gaseous fuels
 
4.1 Electricity generation using solar photovoltaic technology
The activity covers construction or operation of electricity generation facilities that produce electricity using solar photovoltaic
 
(PV).
The activity consists of activities mainly in Brazil.
 
4.3 Electricity generation from wind power
 
The activity covers development of electricity generation facilities that produce electricity from wind
 
power. Equinor is engaged in
offshore wind projects conducted through equity accounted investment in UK, Germany, Poland and the US.
 
5.12 Underground permanent geological storage of CO
2
 
The activity consists of the Northern Lights project
4.29 Electricity generation from fossil gaseous fuels
The activity consists of the Triton power plant acquired in the third quarter of 2022. The current activity is to provide electricity
 
during
periods of low output from solar and wind from a gas turbine (CCGT) that uses natural gas. Work has started to
 
prepare the power
plant to use up to 30% hydrogen from 2027, with an ambition to eventually increase to 100% hydrogen.
 
 
Proportion of taxonomy - eligible economic activities in total capex including equity
 
accounted investments:
 
2022
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
291
Taxonomy-eligible economic activities
Mandatory
Capex KPI
Voluntary
Capex KPI
including
equity
accounted
investments
Electricity generation from wind power
1%
11%
Electricity generation using solar photovoltaic technology
1%
1%
Underground permanent geological storage of CO2
0%
1%
Storage of electricity
1%
0%
Total
3%
13%
Appendix 1
Mandatory KPIs
KPI denominators
Turnover
Total turnover consists of the reported revenue for contracts with customers included in the revenue line item and presented in note 5
Segments in the consolidated financial statements. The revenue included in the numerator and
 
denominator in 2021 consisted of
revenue included in the consolidated financial statement. Equinor has reassessed the definition
 
in accordance with updated
guidelines. Net income/(loss) from equity accounted investments and other income (i.e. gain on
 
divestment of assets) are excluded
from the definition of the mandatory KPI, and not part of the revenue denominator. For Equinor the KPI denominator related to
turnover will be highly impacted by changes in commodity prices.
The 2021 turnover KPI has been updated to include revenue for contracts with customers as described
 
above. The total updated 2021
turnover KPI is 0% which is the same as reported in 2021.
Capex
Total capital expenditures consist of additions to property,
 
plant and equipment including right of use assets line item as specified in
note 12 Property, plant and equipment and additions to intangible assets as specified in note 13 Intangible assets to the Consolidated
financial statements. Additions excludes additions and subsequent changes in estimated asset retirement obligations
 
based on policy
interpretation of the delegated act. This is an interpretation which has been aligned with industry
 
practice and has been updated from
our prior year definition. Capitalised exploration and acquisition costs of oil and gas prospects related to
 
exploration are recognised as
intangible assets, and by interpretation of the Taxonomy regulation, considered to be included the KPI denominator, as this is a part of
Equinor’s ongoing activity (see assessment below). Goodwill acquired through business
 
combinations is excluded from the capital
expenditure KPI.
 
The 2021 capex KPI has been updated to include capex related to the Hywind/Tampen project in the numerator and excluding ARO
additions in the denominator. The total updated 2021 capex KPI is 2% which is the same as reported in 2021.
 
(in USD million)
Note
2022
Additions to PP&E, intangibles and equity accounted investments
5
 
9,994
 
Less:
Additions to Equity accounted investments
15
(337)
Goodwill Additions
13
(36)
Capex denominator as defined by the EU Taxonomy
 
9,621
 
Opex
Total operating expenditures under the Taxonomy
 
cover direct non-capitalised costs that relate to research and development, building
renovation measures, short-term lease, maintenance and repair, and any other direct expenditures relating to the day-to-day servicing
of assets of property, plant and equipment that are necessary to ensure the continued and effective functioning of such assets.
 
The operating expenditures included in the numerator and denominator in 2021 were considered
 
to be represented by the reported
amounts included in the operating expenses and selling, general and administration expense line items
 
in the Consolidated financial
statements. Equinor has reassessed the opex definition in accordance with updates from the
 
regulators and industry practice. Per the
 
 
 
 
292
 
Equinor, Annual Report on Form 20-F 2022
 
above description the “other direct expenditures relating to the day-to-day servicing of assets of
 
property” has been narrowed in scope
to only include direct
maintenance related expenses. This results in the operating expenditures in 2022 consisting
 
of a subset of the
operating expenditures in the income statement and does not include any selling, general and
 
administrative expenditures,
depreciation, amortisation, impairment and exploration expenses
.
 
The opex denominator and numerator have been updated in accordance with the narrow definition
 
as described below. There were no
opex related to the eligible activities in 2021, hence the updated opex KPI for 2021 has been changed
 
from 2% to 0%.
Application of the KPIs
The definition of the capex KPI includes intangible assets in accordance with IAS 38. Acquired goodwill
 
and capitalised costs
according to the successful efforts method under IFRS 6 is out of the scope of IAS 38. The rationale for
 
excluding IFRS 6 from the
capex KPI is not clearly stated in the Taxonomy regulation. Equinor regards exploration activities as part of the ongoing core activities
and has included capitalised exploration costs in the capex denominator. The exploration costs are not covered by the EU Taxonomy
opex definition and not included in the opex KPI. Capitalised exploration expenditures do not have
 
significant effect on the reported
capex KPIs for the year-end 2022.
 
The denominators are calculated based on reported IFRS numbers in the Consolidated financial
 
statements. For Equinor this has the
effect that the proceeds from the sale of the Norwegian State’s (SDFI) oil production on the NCS, that Equinor markets
 
and sells on
their behalf (see note 27 Related Parties to the Consolidated financial statements), that
 
is reported on gross basis and recognised as
revenue in the income statement, will have a negative impact on the reported KPI related
 
to taxonomy-eligible and aligned revenue.
Total purchases of oil and natural gas liquids from the Norwegian state amounted to USD 13 billion in 2022 and USD 10 billion in
2021.
KPI numerators
The KPI numerators consist of the taxonomy-eligible and aligned part of the turnover, operating expenses and capital expenditures
included in the denominator.
When identifying taxonomy-eligible and aligned economic activities within the Equinor group, the
 
starting point has been the reporting
entities and profit centres established for group reporting purposes and included in the group
 
consolidation system. For reporting
entities with one economic activity that has been assessed as a taxonomy-eligible activity, total revenue, total capex additions and
opex as defined above are included in the calculation of the KPIs.
For reporting entities with several taxonomy-eligible economic activities, and where both eligible and non-eligible
 
economic activities
have been identified, the eligible economic activities are identified per cluster, profit centre, or lower levels depending on where the
cost related to the activity is recorded in Equinor.
 
Technical screening procedures
Equinor implemented the assessment of the technical screening criteria for the environmental
 
objectives climate change mitigation
and climate change adaptation in accordance with the Delegated act related to article 8. For 2022 Equinor’s
 
activity primarily relate
relates to activities within the climate change mitigation objective.
An economic activity contributes substantially to climate change mitigation where that activity contributes
 
substantially to the
stabilisation of greenhouse gas concentrations in the atmosphere at a level which prevents
 
dangerous anthropogenic interference with
the climate system consistent with the long-term temperature goal of the Paris Agreement through the
 
avoidance or reduction of
greenhouse gas emissions or the increase of greenhouse gas removals, including through
 
process innovations or product
innovations.
 
Equinor have carried out the assessment process as followed:
 
Assessment of substantial contribution
Compliance with the technical screening criteria is generally tested individually for each economic
 
activity unless the criteria allow
compliance to be assessed at the level of the entire economic activity, an operating segment or the group as a whole.
 
Assessment of do no significant harm (DNSH)
The purpose of the do no significant harm assessment is to prevent investment processes, which
 
would focus on a particular
environmental or social objective without sufficient consideration for the other five environmental objectives. The assessments
 
mainly
reflect legal requirements under EU regulations.
Assessment minimum safeguards
Equinor has a group wide approach to ensuring compliance with the minimum safeguards. Equinor is committed
 
to respecting human
rights in all business processes. To prevent human right violations, Equinor adhere to external standards and defines its own
principles and policies.
 
Equinor, Annual Report on Form 20-F 2022
 
293
Appendix 2
The difference between the mandatory 3% Capex KPI as defined within the EU Taxonomy and the 14% REN / LCS Gross Capex* is
mainly related to eligible activity in equity accounted investments which is included within the voluntary EU
 
taxonomy KPI. In addition,
additions to right-of-use asset (leasing) are excluded and additions to goodwill are included in the
 
REN / LCS Gross Capex* which
differs in treatment to the EU taxonomy KPI.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
294
 
Equinor, Annual Report on Form 20-F 2022
 
Appendix 3
2022 Revenue
SUBSTANTIAL
CONTRIBUTION
CRITERIA
DOES NOT SIGNIFICANT HARM
Economic activities
Code
Absolute
Revenue
USD
million
Proportio
n of
Revenue
%
Climate
change
mitigatio
n %
Climate
change
adaptatio
n %
Climate
change
mitigatio
n
Climate
change
adaptatio
n
Water
and
marine
resource
s
Circular
econom
y
Pollutio
n
Biodiversit
y and
ecosyste
ms
Minimum
safeguard
s
Taxonomy-
aligned
proportion
of Revenue
%
A. TAXONOMY-ELIGIBLE ACTIVITIES (A.1. + A.2.)
A.1. Environmentally sustainable activities (Taxonomy-
aligned)
Electricity generation from wind power
D35.1
1
0
 
0%
100%
0%
Y
Y
Y
Y
Y
Y
Y
0%
Electricity generation using solar photovoltaic
technology
F42.2
2
0
 
0%
100%
0%
Y
Y
Y
Y
Y
Y
Y
0%
Revenue of environmentally sustainable activities
(Taxonomy-aligned) (A.1.)
0
 
0%
A.2. Taxonomy-eligible but not environmentally
sustainable activities (not Taxonomy-aligned activities)
Electricity generation from wind power
D35.1
1
0
 
0%
Electricity generation using solar photovoltaic
technology
F42.2
2
0
 
0%
Storage of electricity
0
 
0%
Revenue of Taxonomy-eligible but not environmentally
sustainable activities (not Taxonomy-aligned activities)
(A.2)
0
 
0%
B. TAXONOMY NON-ELIGIBLE ACTIVITIES
Revenue of Taxonomy-non-eligible activities (B)
(150,262)
100%
Total (A+B)
(150,262)
100%
 
2022 Capex
SUBSTANTIAL
CONTRIBUTION
CRITERIA
DOES NOT SIGNIFICANT HARM
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
295
Economic activities
Code
Absolute
Capex
USD
million
Proportio
n of
Capex %
Climate
change
mitigatio
n %
Climate
change
adaptatio
n %
Climate
change
mitigatio
n
Climate
change
adaptatio
n
Water
and
marine
resource
s
Circular
econom
y
Pollutio
n
Biodiversit
y and
ecosyste
ms
Minimum
safeguard
s
Taxonomy-
aligned
proportion
of Capex %
A. TAXONOMY-ELIGIBLE ACTIVITIES (A.1. + A.2.)
A.1. Environmentally sustainable activities (Taxonomy-
aligned)
Electricity generation from wind power
D35.1
1
92
 
1.0 %
100%
0%
Y
Y
Y
Y
Y
Y
Y
1.0 %
Electricity generation using solar photovoltaic
technology
F42.2
2
66
 
0.7 %
100%
0%
Y
Y
Y
Y
Y
Y
Y
0.7 %
Capex of environmentally sustainable activities
(Taxonomy-aligned) (A.1.)
157
 
1.6 %
A.2. Taxonomy-eligible but not environmentally
sustainable activities (not Taxonomy-aligned activities)
Electricity generation from wind power
D35.1
1
35
 
0.4 %
Electricity generation using solar photovoltaic
technology
F42.2
2
0
 
0.0 %
Storage of electricity
52
 
0.5 %
Capex of Taxonomy-eligible but not environmentally
sustainable activities (not Taxonomy-aligned activities)
(A.2)
87
 
0.9 %
B. TAXONOMY NON-ELIGIBLE ACTIVITIES
Capex of Taxonomy-non-eligible activities (B)
9,376
 
97.5 %
Total (A+B)
9,621
 
100.0 %
 
2022 Opex
SUBSTANTIAL
CONTRIBUTION
CRITERIA
DOES NOT SIGNIFICANT HARM
Economic activities
Code
Absolute
Opex
USD
million
Proportion
of Opex %
Climate
change
mitigati
on %
Climate
change
adaptatio
n %
Climate
change
mitigatio
n
Climate
change
adaptatio
n
Water
and
marine
resource
s
Circular
econom
y
Pollutio
n
Biodiversi
ty and
ecosyste
ms
Minimum
safeguard
s
Taxonomy-
aligned
proportion
of Opex %
A. TAXONOMY-ELIGIBLE ACTIVITIES (A.1. + A.2.)
A.1. Environmentally sustainable activities (Taxonomy-
aligned)
Electricity generation from wind power
D35.1
1
0
 
0%
100%
0%
Y
Y
Y
Y
Y
Y
Y
0%
Electricity generation using solar photovoltaic
technology
F42.2
2
0
 
0%
100%
0%
Y
Y
Y
Y
Y
Y
Y
0%
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
296
 
Equinor, Annual Report on Form 20-F 2022
 
Opex of environmentally sustainable activities
(Taxonomy-aligned) (A.1.)
0
 
0%
0%
A.2. Taxonomy-eligible but not environmentally
sustainable activities (not Taxonomy-aligned activities)
Electricity generation from wind power
D35.1
1
0
 
0%
Electricity generation using solar photovoltaic
technology
F42.2
2
0
 
0%
Storage of electricity
0
 
0%
Opex of Taxonomy-eligible but not environmentally
sustainable activities (not Taxonomy-aligned activities)
(A.2)
0
 
0%
B. TAXONOMY NON-ELIGIBLE ACTIVITIES
Opex of Taxonomy-non-eligible activities (B)
1,555
 
100%
Total (A+B)
1,555
 
100%
Equinor, Annual Report on Form 20-F 2022
 
297
5.5 Production per field
The following tables shows the regional production
 
by field.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
298
 
Equinor, Annual Report on Form 20-F 2022
 
E&P Norway - Equinor operated fields, average daily
 
entitlement production
Geographical area
Equinor's equity
interest in %
On
stream
 
Licence expiry
date
Average
production in
2022 mboe/day
Field
Johan Sverdrup
The North Sea
42.63
2019
2036-2037
227
Troll Phase 1 (Gas)
The North Sea
30.58
1996
2030
210
Oseberg
 
The North Sea
49.30
1988
2031
102
Gullfaks
The North Sea
51.00
1986
2036
83
Aasta Hansteen
The Norwegian Sea
51.00
2018
2041
74
Visund
The North Sea
53.20
1999
2034
67
Martin Linge
The North Sea
51.00
1)
2021
2027
56
Åsgard
The Norwegian Sea
34.57
1999
2027
48
Tyrihans
The Norwegian Sea
58.84
2009
2029
42
Gina Krog
The North Sea
58.70
2017
2032
37
Snorre
 
The North Sea
33.28
1992
2040
35
Snøhvit
The Barents Sea
36.79
2007
2035
28
Kvitebjørn
The North Sea
39.55
2004
2031
24
Fram
 
The North Sea
45.00
2003
2040
21
Troll Phase 2 (Oil)
The North Sea
30.58
1995
2030
19
Statfjord Unit
The North Sea
64.10
2) 3)
1979
2026
18
Gudrun
The North Sea
36.00
2014
2032
18
Grane
The North Sea
36.61
2003
2030
17
Sleipner West
The North Sea
58.35
1996
2028
15
Mikkel
 
The Norwegian Sea
43.97
2003
2028
14
Heidrun
 
The Norwegian Sea
13.04
1995
2024-2025
11
Tordis area
The North Sea
41.50
1994
2040
11
Vigdis area
The North Sea
41.50
1997
2040
9
Norne
The Norwegian Sea
39.10
1997
2026
9
Kristin
The Norwegian Sea
54.82
2005
2027-2033
9
Trestakk
The Norwegian Sea
59.10
2019
2029
8
Valemon
The North Sea
66.78
2015
2031
7
Alve
The Norwegian Sea
53.00
2009
2029
7
Urd
The Norwegian Sea
63.95
2005
2026
4
Statfjord North
The North Sea
45.00
2) 3)
1995
2026
4
Sleipner East
The North Sea
59.60
1993
2028
3
Morvin
The Norwegian Sea
64.00
2010
2027
3
Utgard
The North Sea
38.44
3)
2019
2028
2
Statfjord East
The North Sea
43.25
2) 3)
1994
2026-2040
2
Gungne
 
The North Sea
62.00
1996
2028
2
Sigyn
The North Sea
60.00
2002
2035
2
Tune
The North Sea
50.00
2002
2025-2032
1
Sygna
The North Sea
43.43
2) 3)
2000
2026-2040
1
Byrding
The North Sea
70.00
2017
2024-2035
1
Fram H Nord
The North Sea
49.20
2014
2024-2035
0
Sindre
The North Sea
72.91
2017
2023-2034
0
Veslefrikk
The North Sea
18.00
1989
2025-2031
0
Njord
The North Sea
27.50
1997
2034
0
Gimle
The North Sea
75.81
2006
2023-2034
0
Heimdal
The North Sea
29.44
1985
2023
0
Total Equinor operated fields
1,251
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
299
E&P Norway - Partner operated fields, average daily
 
entitlement production
Geographical area
Equinor's equity
interest in %
Operator
 
On
stream
 
Licence expiry
date
Average
production in
2022 mboe/day
Field
Skarv
The Norwegian Sea
36.17
Aker BP ASA
2013
2029-2036
52
Ormen Lange
The Norwegian Sea
25.35
A/S Norske
 
Shell
2007
2040-2041
43
Ivar Aasen
The North Sea
41.47
Aker BP ASA
2016
2029-2036
14
Goliat
The Barents Sea
35.00
Vår Energi AS
2016
2042
11
Ekofisk area
 
The North Sea
0.00
1)
ConocoPhillips Skandinavia
AS
1971
2048
7
Ærfugl Nord
The Norwegian Sea
30.00
Aker BP ASA
2021
2033
4
Marulk
The Norwegian Sea
33.00
Vår Energi AS
2012
2025
4
Tor II
The North Sea
0.00
1)
ConocoPhillips Skandinavia
AS
2020
2028-2048
1
Enoch
The North Sea
11.78
Repsol Sinopec
 
North Sea Ltd.
2007
2024
0
Total partner operated fields
136
Total E&P Norway including share of equity accounted production
1,387
1) On 30 September 2022, Equinor completed the transaction
 
to divest its 7.60% stake in Ekofisk and its 6.64%
 
stake in Tor 2 and sell a 19%
stake in Martin Linge to Sval Energi. Upon completion,
 
Equinor holds a 51% operating interest in Martin
 
Linge. The transaction is effective
from 1 January 2022. The volumes for the first three
 
quarters of 2022 pertain to Equinor’s
 
stakes in Ekofisk, Tor 2 and Martin
 
Linge prior to the
transaction.
2) On 31 May 2022, Equinor completed the transaction
 
to acquire all of Spirit Energy’s production licences in the
 
Statfjord area on the
Norwegian and the UK continental shelves. Upon
 
completion, Equinor increased its stake in Statfjord on
 
the NCS and holds a 14.53% stake in
Statfjord unit UK. With the transaction, Equinor’s
 
operating interest in Statfjord on the NCS
 
increased as follows: Statfjord unit from 44.34% to
64.10%, Statfjord North from 21.88% to 45.00%;
 
Statfjord East from 31.69% to 43.25%, Sygna from 30.71%
 
to 43.43%. The commercial
effective date of the transaction is 1 January 2021.
 
The volumes for the period before 1 June 2022 pertain
 
to Equinor’s stake in Statfjord prior
to the transaction.
3) The Statfjord and Utgard fields in the North
 
Sea span the boundary between the Norwegian and
 
UK continental shelves. The volumes
pertain to Equinor’s operating interest in
 
Statfjord and Utgard on the NCS. For the volumes
 
pertaining to Equinor’s operating interest in
Statfjord and Utgard on the UKCS, please see section
 
3.1.2 E&P International.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
300
 
Equinor, Annual Report on Form 20-F 2022
 
E&P International - Average daily equity production
Field
Country
Equinor's
equity
interest in %
Operator
 
On
stream
 
Licence
expiry date
Average daily
equity
production in
2022
 
mboe/day
Americas (excluding US)
69
Roncador
Brazil
25.00
 
Petróleo Brasileiro S.A.
 
1999
2052
34
Peregrino
Brazil
60.00
 
Equinor Brasil Energia Ltda.
 
2011
2040
17
Hebron
Canada
9.01
 
ExxonMobil Canada Properties
 
2017
HPB
1)
12
Hibernia/Hibernia Southern
Extension
2)
Canada
Varies
 
Hibernia Management and Development
Corporation Ltd.
 
1997
HPB
1)
5
Bajo del Toro
Argentina
50.00
Yacimientos Petrolíferos Fiscales S.A.
2022
2055
1
Africa
 
 
183
Block 17
Angola
22.16
TotalEnergies E&P Angola S.A.
2001
2045
85
In Salah
Algeria
31.85
Sonatrach
3)
2004
2027
31
Eni In Salah Limited
Equinor In Salah AS
Agbami
Nigeria
20.21
Star Deep Water Petroleum Limited
 
(an affiliate of Chevron in Nigeria)
2008
2042
21
Block 15
Angola
12.00
Esso Exploration Angola Block 15 Limited
2004
2032
17
In Amenas
Algeria
45.90
Sonatrach
3)
2006
2027
15
Eni In Amenas Limited
Equinor In Amenas AS
Block 31
Angola
13.33
BP Exploration (Angola) Ltd
2012
2031
8
Murzuq
Libya
10.00
Akakus Oil Operations
2003
2037
7
Eurasia
63
ACG
Azerbaijan
7.27
BP Exploration (Caspian Sea) Limited
1997
2049
30
Mariner
UK
65.11
 
Equinor UK Limited
 
2019
HBP
1)
16
Corrib
Ireland
36.50
 
Vermilion Exploration and Production
Ireland Limited
 
2015
2031
9
Kharyaga
4)
Russia
0.00
 
Zarubezhneft-Production Kharyaga LLC
 
1999
-
4)
3
Utgard
5)
UK
38.00
 
Equinor Energy AS
 
2019
HBP
1)
2
Statfjord Unit
5)
UK
14.53
 
Equinor Energy AS
 
1979
HBP
1)
2
Barnacle
6)
UK
100.00
 
Equinor UK Limited
 
2019
HBP
1)
0
Total E&P International
315
Equity accounted production
13
Bandurria Sur
Argentina
30.00
Yacimientos Petrolíferos Fiscales S.A.
2015
2050
10
North Danilovskoye
4)
Russia
0.00
 
AngaraOil LLC
 
2020
-
4)
3
North Komsomolskoye
4)
Russia
0.00
 
SevKomNeftegaz LLC
 
2018
-
4)
1
Total E&P International including share of equity accounted production
328
1)
Held by Production (HBP): A leasehold interest
 
that is perpetuated beyond its primary term as
 
long as there is production in paying
quantities from well(s) on the lease or lease(s) pooled
 
therewith.
 
2)
Equinor's equity interests are 5.0% in Hibernia
 
and 9.26% in Hibernia Southern Extension.
3)
The complete name for Sonatrach is Société nationale
 
de transport et de commercialisation d’hydrocarbures.
4)
In February 2022, Equinor decided to stop new investments
 
in Russia. Reporting of production stopped in April and
 
as of the end of 2022
Equinor had transferred its 30% ownership interest
 
in Kharyaga to the operator and participating
 
interest of 49% in North Danilovskoye
and 33.33% in North Komsomolskoye to Rosneft.
 
The volumes for the first three months of 2022
 
pertain to Equinor’s stakes in Kharyaga,
North Danilovskoye and North Komsomolskoye prior
 
to the transaction. For more information, see note
 
6 Acquisitions and disposals to the
Consolidated financial statements.
5)
The Utgard and Statfjord Unit fields span the boundary
 
between the Norwegian and UK continental
 
shelves. In this table we report only
volumes pertaining to the Equinor share in UKCS.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
301
6)
 
Actual production for Barnacle was 0.4 mboe/day.
E&P USD - Average daily equity production
Field
Country
Equinor's equity
interest in %
Operator
 
On
stream
 
Licence
expiry date
Average daily
equity
production in
2022 mboe/day
Appalachian (APB)
1)
US
Varies
2)
Equinor/others
3)
2008
HBP
5)
 
216
 
Tahiti
US
25.00
 
Chevron USA Inc.
 
2009
HBP
5)
 
25
 
Caesar Tonga
US
46.00
 
Anadarko U.S. Offshore LLC
 
2012
HBP
5)
 
21
 
Julia
US
50.00
 
ExxonMobil Corporation
 
2016
HBP
5)
 
16
 
St. Malo
US
21.50
 
Chevron USA Inc.
 
2014
HBP
5)
 
15
 
Jack
US
25.00
 
Chevron USA Inc.
 
2014
HBP
5)
 
12
 
Big Foot
US
27.50
 
Chevron USA Inc.
 
2018
HBP
5)
 
9
 
Stampede
US
25.00
 
Hess Corporation
 
2018
HBP
5)
 
7
 
Titan
US
100.00
 
Equinor USA E&P Inc.
 
2018
HBP
5)
 
1
 
Heidelberg
4)
US
12.00
 
Anadarko U.S. Offshore LLC
 
2016
HBP
5)
 
0
 
Total E&P USA
 
324
 
1)
Appalachian basin contains Marcellus and Utica formations.
 
2)
Equinor’s actual equity interest varies depending
 
on wells and area.
3)
Operators are Equinor USA Onshore Properties
 
Inc, Chesapeake Operating LLC, Southwestern
 
Production Company, Chief Oil &
Gas LLC, and several other operators.
 
4)
Actual production for Heidelberg was 0.4 mboe/day.
5)
Held by Production (HBP): A leasehold interest
 
that is perpetuated beyond its primary term as
 
long as there is production in paying
quantities from well(s) on the lease(s) pooled therewith.
302
 
Equinor, Annual Report on Form 20-F 2022
 
5.6 Additional sustainability information
5.6.1 About the sustainability elements of the report
Reporting standards
 
This report has been prepared in accordance with the Global Reporting Initiative (GRI) Standards (2016, core option). The
sustainability report should be read in conjunction with the GRI index available at equinor.com, to get an overview of the full
extent of the report. We view this report to be our Communication on Progress to the UN Global Compact (advanced reporting
level). We also use reporting guidance from IPIECA, the global oil and gas industry association for environmental and social
issues, and recommendations from the Task Force
 
on Climate-related Financial Disclosures.
Assurance
 
We recognise that the quality of our reported sustainability data can be affected by inherent limitations in accuracy in raw data,
calculation and estimation procedures including assumptions for such purposes, and in manual transfer of data. We strive to
achieve data quality in line with expectations set out in GRI 101 “Reporting principles” and continue our work to improve
internal reporting and control processes in line with the COSO framework for internal control. These processes are laid out in
our internal performance framework. Examples of our internal assurance mechanisms are independent internal audits and
verifications, quarterly reviews of the data at business area and corporate level, and an annual process where all reported
sustainability data are reviewed by named individuals and their relevant leaders confirm, in documented form, that quality
assurance has been performed. This report has been externally assured by EY,
 
with reasonable level of assurance for
selected climate, environment and safety indicators, and a limited level of assurance for the rest of the report, excluding
forward looking information and field-specific reporting. The independent assurance statement, as listed in appendix,
concludes that the report is presented in all material respects, in accordance with the GRI Standards: Core option.
 
Reporting boundaries
 
Defining consistent boundaries for sustainability reporting is challenging due to the complexity of ownership and operational
arrangements, such as joint operating agreements. We strive to be consistent and transparent about variations in boundaries
and provide a complete report in line with industry practice.
 
●
 
Environmental data is, unless otherwise stated, reported on a 100% basis for our operated assets, facilities and
vessels, including subsidiaries and operations where we are the technical service provider, and for contracted
drilling rigs and flotels (“operational control basis”).
 
●
 
Scope 1 CO
₂
 
emissions and upstream CO
₂
 
intensity are reported both on an operational control basis and on
equity basis (financial ownership interest).
 
●
 
Scope 3 greenhouse gas emissions are reported on the basis of equity (products sold). Maritime emissions are
reported from maritime vessels under Equinor contract, including project and supply vessels, drilling rigs, and
tankers transporting both Equinor and third-party volumes.
 
●
 
Scope 3 emissions related to business travel is for Equinor employees only.
 
●
 
Health and safety incident data is reported for our operated assets, facilities and vessels, including subsidiaries
and operations where we are the technical service provider. These include contracted drilling rigs, flotels, vessels,
projects and modifications, and transportation of personnel and products, using a risk-based approach.
 
●
 
• Economic and energy production data are reported on an equity basis, unless otherwise stated.
 
●
 
• Workforce data covers employees in our direct employment. Temporary
 
employees are not included.
 
●
 
• Human rights data is collected from operated and non-operated assets.
 
Operations acquired or disposed of during the year are included for the period in which we owned them, unless otherwise
stated. Entities that we do not control, but have significant influence over, are included in the form of disclosures of
management approach. The report does not include data from equity interest fields/projects, such as joint ventures, where we
are not operator. Exceptions are for climate data or where specified.
 
Restatements
 
Historic numbers are sometimes adjusted due to for example changes in reporting principles, changes of calculation factors
used by authorities, or re-classification of incidents after investigations. We restate historic numbers and explain the changes if
the adjustment represents a change of minimum 5% for indicators with reasonable level of assurance, and 10% for indicators
with limited level of assurance.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
303
5.6.2 Task
 
Force on Climate-related Financial Disclosures (TCFD) reference index 2022
 
Equinor aligns its climate-related disclosures with the recommendations of the Task Force on Climate related Financial Disclosures.
Relevant context and disclosures for each of the TCFD recommendations can be found at
 
several places in the following disclosure
products:
●
Equinor’s 2022 Integrated Annual Report (IR)
●
Sustainability performance data (datahub on Equinor.com) (SPD)
●
Equinor’s 2022 CDP response (CDP)
TCFD recommendation
Reference to Equinor disclosure products
Governance – Disclose the organisation’s governance around climate-related risks and opportunities
a) Describe the board’s oversight of
climate-related risks and opportunities.
●
IR 1.8 – Governance and risk management
●
IR 5.1 – Board statement on corporate governance, subitem 9 (The work of the board
of directors) and subitem 10 (Risk management and internal control)
●
CDP C1 - Governance
b) Describe management’s role in
assessing and managing climate-related
risks and opportunities.
●
IR 1.8 – Governance and risk management
●
CDP C1 – Governance
●
CDP C2 – Risks and opportunities
Strategy – Disclose the actual and potential impacts of climate-related risks and opportunities on the
 
organisation’s businesses,
strategy, and financial planning where such information is material
a) Describe the climate-related risks and
opportunities the organisation has identified
over the short, medium, and long term.
●
IR 1.8 – Governance and risk management
●
IR 2.3 – Low carbon
●
IR 2.3.1 – Net zero pathway
●
IR 2.3.2 – Emissions reductions
●
IR 5.2 – Risk factors
●
CDP C2 – Risks and opportunities
b) Describe the impact of climate-related
risks and opportunities on the
organisation’s businesses, strategy, and
financial planning.
●
IR 1.5 – Equinor’s strategy
●
IR 1.7 – Sustainability at Equinor
●
IR 2 – Enterprise level performance, Performance 2022
●
IR 2.2.2 – Profitable portfolio, Portfolio stress test, Physical climate risk
●
IR 2.3 – Low carbon
●
IR 2.3.1 – Net zero pathway
●
IR 2.3.2 – Emissions reductions
●
IR 3.2 – High-value growth in renewables
●
IR 3.3 – Marketing, midstream and processing (MMP), including new market
opportunities in low carbon solutions
●
IR 4.1 Consolidated financial statements of the Equinor group – Notes to the
Consolidated financial statements – Note 3: Consequences of initiatives to limit
climate changes and Note 14:
 
Impairments,
 
●
CDP C2 – Risks and opportunities
●
CDP C3 – Business strategy
 
c) Describe the resilience of the
organisation’s strategy, taking into
consideration different climate-related
scenarios, including a 2°C or lower
scenario.
●
IR 1.5 – Equinor’s strategy
●
IR 1.7 – Sustainability at Equinor
●
IR 2 – Enterprise level performance, Performance 2022
●
IR 2.2.2 – Profitable portfolio, Portfolio stress test, Physical climate risk
●
IR 4.1 Consolidated financial statements of the Equinor group – Notes to the
Consolidated financial statements – Note 3: Consequences of initiatives to limit
climate changes and Note 14:
 
Impairments,
●
CDP C3 – Business strategy
 
Risk management – Disclose how the organisation identifies, assesses, and manages climate-related risks
a) Describe the organisation’s processes
for identifying and assessing climate-
related risks.
●
IR 1.8 – Governance and risk management
●
IR 2.2.2 – Profitable portfolio, Portfolio stress test, Physical climate risk
●
CDP C2 – Risks and opportunities
b) Describe the organisation’s processes
for managing climate-related risks
●
IR 1.8 – Governance and risk management
●
IR 2.2.2 – Profitable portfolio, Portfolio stress test, Physical climate risk
●
CDP C2 – Risks and opportunities
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
304
 
Equinor, Annual Report on Form 20-F 2022
 
c) Describe how processes for identifying,
assessing, and managing climate-related
risks are integrated into the organisation’s
overall risk management.
●
IR 1.8 – Governance and risk management
●
CDP C2 – Risks and opportunities
Metrics and targets – Disclose the metrics and targets used to assess and manage relevant
 
climate-related risks and opportunities
where such information is material
a) Disclose the metrics used by the
organisation to assess climate-related risks
and opportunities in line with its strategy
and risk management process.
●
IR Introduction – Equinor’s Energy transition plan
●
IR 2 – Enterprise level performance, Performance 2022
●
IR 2.2.2 – Profitable portfolio, Portfolio stress test, Physical climate risk
●
IR 2.3.1 Net zero pathway
●
IR 2.3.2 – Emissions reductions
●
CDP C4 – Targets and performance
●
SPD Climate
b) Disclose Scope 1, Scope 2, and, if
appropriate, Scope 3 greenhouse gas
(GHG) emissions, and the related risks.
●
IR Introduction – Equinor’s Energy transition plan
●
IR 2.3.1 Net zero pathway
●
IR 2.3.2 – Emissions reductions
●
CDP C4 – Targets and performance
●
SPD Climate
c) Describe the targets used by the
organisation to manage climate-related
risks and opportunities and performance
against targets.
●
IR Introduction – Equinor’s Energy transition plan
●
IR 2.3.1 Net zero pathway
●
IR 2.3.2 – Emissions reductions
●
CDP C4 – Targets and performance
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
305
5.6.3 Overview of
 
climate ambitions
Ambitio
n year
Ambitions
Boundary
Scope
Baseline year
2025
Upstream CO
₂
 
intensity <8kg CO
₂
/boe
Operational control
 
100%, upstream
Scope 1 CO
₂
NA
>30% share of
 
annual gross capex
 
to renewables and
low carbon solutions
Equinor gross capex
NA
NA
2030
Net 50% emission reduction
Operational control
 
100%
Scope 1 and 2 CO
₂
 
and CH
4
2015
>50% share of annual gross
 
capex to renewables and
low carbon solutions
Equinor gross capex
NA
NA
Reduce net carbon intensity
 
by 20%
2)
Scope 1 and 2
 
GHG emissions (100%
 
operator
basis). Scope 3 GHG
 
emissions from use of
 
sold
products (equity production), net of negative
emissions. Energy production (equity)
Scope 1, 2 and 3 CO
₂
 
and CH
4
2019
Renewable energy
 
capacity 12-16
 
GW
1)
Equity basis
Installed capacity (GW)
NA
Upstream CO
₂
 
intensity ~6kg CO
₂
/boe
Operational control
 
100%, upstream
Scope 1 CO
₂
NA
Carbon Capture
 
and Storage
(CCS): 5-10
 
million
 
tonnes
CO
₂
 
(geological) storage per
year
Equity basis
NA
NA
Eliminate routine flaring
Operational control
 
100%
Flared hydrocarbons
NA
Keep methane emission intensity near zero
Operational control
 
100%
CH
4
2016
Reduce maritime emissions by 50% in Norway
Scope 1 GHG emissions
 
from drilling rigs
 
and
floatels. Scope 3 GHG
 
emissions from all vessel
contracted by Equinor.
Scope 1 and 3 CO
₂
 
and CH
4
2005
2035
Carbon Capture
 
and Storage
 
(CCS): 15-30
 
million
tonnes CO
₂
 
(geological) storage per year
Equity basis
NA
NA
Establishing a 10%
 
market share of
 
hydrogen in
Europe
NA
NA
NA
Reduce net carbon intensity
 
by 40%
2)
Scope 1 and 2
 
GHG emissions (100%
 
operator
basis). Scope 3 GHG
 
emissions from use of
 
sold
products (equity production), net of negative
emissions. Energy production (equity)
Scope 1, 2 and 3 CO
₂
 
and CH
4
2019
2040
Reduce absolute emissions in Norway
 
by 70%
Operational control
 
100%, Norway
Scope 1 and 2 CO
₂
 
and CH
4
2005
Net-zero emissions and
 
100% net carbon
 
intensity
reduction
2)
Scope 1 and 2
 
GHG emissions (100%
operator basis). Scope 3
 
GHG emissions from
Scope 1, 2 and 3 CO
₂
 
and CH
4
2019
 
 
 
 
exhibit154p306i0 exhibit154p306i1
306
 
Equinor, Annual Report on Form 20-F 2022
 
2050
use of
 
sold products (equity production), net
of negative emissions. Energy production
(equity)
Reduce absolute emissions in Norway to
 
near zero
Operational control
 
100% Norway
Scope 1 and 2 CO
₂
 
and CH
4
2005
Reduce maritime emissions by 50% globally
Scope 1 GHG emissions
 
from drilling rigs
 
and
floatels. Scope 3 GHG
 
emissions from all vessel
contracted by Equinor
Scope 1 and 3 CO
₂
 
and CH
4
2008
 
Including Equinor’s equity
 
share of Scatec ASA.
 
For more details, please see
 
the Net-GHG emissions and net
 
carbon intensity methodology note
 
on equinor.com.
Equinor, Annual Report on Form 20-F 2022
 
307
5.7 Statements on this report incl. independent auditor reports
Statement on compliance
Today,
 
the board of directors, the chief executive officer and
 
the chief financial officer reviewed and approved the 2022
 
Integrated Annual
report,
 
which includes the board of directors' report,
 
the Equinor ASA Consolidated and parent company annual
 
financial statements as of 31
December 2022, and the sustainability report.
To the best of our knowledge, we confirm that:
●
 
the Equinor Consolidated annual financial statements
 
for 2022 have been prepared in accordance with
 
IFRS as adopted by the European
Union (EU), IFRS as issued by the International
 
Accounting Standards Board (IASB) and additional Norwegian
 
disclosure requirements in
the Norwegian Accounting Act, and that
●
 
the parent company financial statements for Equinor ASA for 2022 have
 
been prepared in accordance with simplified IFRS
 
pursuant to the
Norwegian Accounting Act §3-9 and regulations regarding
 
simplified application of IFRS issued by the
 
Norwegian Ministry of Finance, and
that
 
●
 
the board of directors' report for the group
 
and the parent company is in accordance
 
with the requirements in the Norwegian Accounting
Act and Norwegian Accounting Standard no 16, and
 
that
●
 
the information presented in the financial statements gives
 
a true and fair view of the company's and
 
the group's assets, liabilities, financial
position and results for the period viewed in
 
their entirety, and that
●
 
the board of directors' report gives a true and
 
fair view of the development, performance,
 
financial position, principal risks and uncertainties
of the company and the group.
14 March 2023
THE BOARD OF DIRECTORS OF
 
EQUINOR ASA
/s/ JON ERIK REINHARDSEN
CHAIR
/s/ ANNE DRINKWATER
DEPUTY CHAIR
/s/ HAAKON BRUUN-HANSSEN
/s/ REBEKKA GLASSER HERLOFSEN
/s/ MICHAEL LEWIS
/s/ JONATHAN LEWIS
/s/ FINN BJØRN RUYTER
/s/ TOVE ANDERSEN
/s/ HILDE MØLLERSTAD
/s/ STIG LÆGREID
/s/ PER MARTIN LABRÅTEN
/s/ TORGRIM REITAN
CHIEF FINANCIAL
 
OFFICER
/s/ ANDERS OPEDAL
 
PRESIDENT
 
AND CEO
 
308
 
Equinor, Annual Report on Form 20-F 2022
 
Recommendation of the corporate assembly
Resolution:
At its meeting of 22 March, the corporate assembly discussed the 2022 annual accounts of Equinor ASA
 
and the Equinor group, and
the board of directors' proposal for the allocation of net income in Equinor ASA.
The corporate assembly recommends that the annual accounts and the allocation of net income proposed
 
by the board of directors
are approved.
Oslo, 22 March 2023
/s/ JARLE ROTH
Chair of the corporate assembly
Corporate assembly
Jarle Roth
Nils Bastiansen
Finn Kinserdal
Kari Skeidsvoll Moe
Kjerstin Fyllingen
Kjerstin R. Braathen
Mari Rege
Trond Straume
Martin Wien Fjell
Merete Hverven
Helge Aasen
Liv B. Ulriksen
Peter B. Sabel
Oddvar Karlsen
Berit Søgnen Sandven
Lars Olav Grøvik
Terje Enes
Per Helge Ødegård
Ingvild Berg Martiniussen
Anne Kristi Horneland
Equinor, Annual Report on Form 20-F 2022
 
309
Independent auditor reports
The report set out below is provided in accordance
 
with law, regulations, and auditing standards and practices generally
 
accepted in Norway,
including International Standards on Auditing (ISAs). Ernst
 
& Young AS (PCAOB ID: 1572) has also issued reports in accordance with
standards of the Public Company Accounting Oversight
 
Board (PCAOB) in the US, which include opinions
 
on the Consolidated financial
statements of Equinor ASA and on the effectiveness of
 
internal control over financial reporting as at 31
 
December 2022. Those reports are set
out on in the 2022 Form 20-
F.
To the Annual Shareholders' Meeting of Equinor ASA
Report on the audit of the financial statements
Opinion
We have audited the financial statements of Equinor ASA (the
 
Company) which comprise the financial statements of
 
the Company and the
consolidated financial statements of the Company and its
 
subsidiaries (the Group). The financial statements
 
of the Company comprise the
balance sheet as at 31 December 2022 and the income
 
statement, statement of comprehensive income, statement
 
of cash flows and
statement of changes in equity for the year then
 
ended and notes to the financial statements,
 
including a summary of significant accounting
policies. The consolidated financial statements of the Group
 
comprise the balance sheet as at 31 December
 
2022, the income statement,
statement of comprehensive income, statement of
 
cash flows and statement of changes in equity for
 
the year then ended and notes to the
financial statements, including a summary of significant
 
accounting policies.
In our opinion
●
 
the financial statements comply with applicable legal
 
requirements,
●
 
the financial statements give a true and fair
 
view of the financial position of the Company
 
as at 31 December 2022 and its financial
performance and cash flows for the year then ended
 
in accordance with simplified application of international
 
accounting standards
according to section 3-9 of the Norwegian Accounting
 
Act,
●
 
the consolidated financial statements give a
 
true and fair view of the financial position
 
of the Group as at 31 December 2022 and
 
its
financial performance and cash flows for the
 
year then ended in accordance with International
 
Financial Reporting Standards as
adopted by the EU.
Our opinion is consistent with our additional report
 
to the audit committee.
Basis for opinion
We conducted our audit in accordance with International
 
Standards on Auditing (ISAs). Our responsibilities
 
under those standards are further
described in
the Auditor’s responsibilities for the
 
audit of the financial statements
 
section of our report. We are independent of the Company
and the Group in accordance with the requirements
 
of the relevant laws and regulations in Norway
 
and the
International Ethics Standards
Board for Accountants’ International Code of Ethics
 
for Professional Accountants (including International
 
Independence Standards)
 
(IESBA
Code), and we have fulfilled our other ethical
 
responsibilities in accordance with these requirements.
 
We believe that the audit evidence we
have obtained is sufficient and appropriate to provide a basis
 
for our opinion.
To the best of our knowledge and belief, no prohibited non-audit services referred to in
 
the Audit Regulation (537/2014) Article 5.1 have
 
been
provided.
We have been the auditor of the Company for 4 years
 
from the election by the general meeting of
 
the shareholders on 15 May 2019 for the
accounting year 2019.
Key audit matters
Key audit matters are those matters that, in our
 
professional judgment, were of most significance
 
in our audit of the financial statements for
2022. These matters were addressed in the context
 
of our audit of the financial statements as
 
a whole and in forming our opinion thereon, and
we do not provide a separate opinion on
 
these matters. For each matter below, our description of how
 
our audit addressed the matter is
provided in that context.
We have fulfilled the responsibilities described in the Auditor’s
 
responsibilities for the audit of the financial statements
 
section of our report,
including in relation to these matters. Accordingly, our audit included the performance
 
of procedures designed to respond to our assessment
 
of
the risks of material misstatement of the financial statements.
 
The results of our audit procedures, including
 
the procedures performed to
address the matters below, provide the basis for our audit opinion on
 
the financial statements.
 
 
 
 
 
 
310
 
Equinor, Annual Report on Form 20-F 2022
 
Impact of climate change and energy transition
 
on the financial statements
Basis for the key audit matter
As described in Note 3 to the Consolidated
 
Financial Statements, the effects of
the initiatives to limit climate changes and the potential
 
impact of the energy
transition are relevant to some of the economic assumptions
 
in the Company’s
estimation of future cash flows. Climate considerations are
 
included directly in
the impairment and deferred tax asset assessments
 
by estimating the CO2
costs in the cash flows, and indirectly as the expected
 
effects of the climate
change are included in the estimated commodity prices.
 
Commodity price
assumptions applied in value-in-use impairment testing and
 
deferred tax asset
assessments are based on management’s best estimate,
 
which differs from the
price-set required to achieve the goals of the Paris
 
Agreement as described in
the International Energy Agency (IEA) World Energy Outlook’s
 
Announced
Pledges Scenario, or the Net Zero Emissions by
 
2050 Scenario.
The impact of the energy transition and potential
 
restrictions by regulators and
market and strategic considerations may also have
 
an effect on the estimated
production profiles and the economic lifetime of
 
the Company’s assets and
projects. In addition, if the Company’s business cases
 
for the oil and gas
producing assets in the future should change materially
 
due to governmental
initiatives to limit climate changes, it could affect the timing of
 
cessation of the
assets and the asset retirement obligations.
Auditing management’s estimate of the impact of climate
 
change and energy
transition on the financial statements is complex and
 
involves a high degree of
judgement. Significant assumptions used in such
 
estimate are commodity prices
and CO2 costs.
We consider the impact of climate change and energy
 
transition on the financial
statements to be a key audit matter given the
 
significance of this matter and the
complexity and uncertainty in the estimates and
 
assumptions used by
management.
Our audit response
 
We obtained an understanding of the Company’s process
 
for
evaluating the impact of climate
change and energy transition on the financial
 
statements.
This included testing controls over management’s review
 
of
the significant assumptions commodity price and CO2
 
costs.
With the support of our firm’s experts in climate change and
energy transition, we evaluated management’s assessment of
the impact of climate change and energy transition
 
on the
financial statements. Our audit procedures among
 
other
comprised the following:
●
 
We evaluated management’s methodology to factor
climate-related matters into their determination of
future commodity price assumptions and compared
those with external benchmarks
 
●
 
We analysed the carbon price assumptions
included in the cash flows for impairment and
deferred tax asset assessments, by comparing
them with current legislation in place in the relevant
jurisdictions and the jurisdictions’ announced
pledges regarding escalation of CO2 costs
●
 
We evaluated management’s sensitivity analyses
over the possible effects of using the commodity
prices and carbon cost assumptions in accordance
with the Net Zero Emission by 2050 Scenario
 
and
Announced Pledges Scenario estimated by the
International Energy Agency (IEA)
●
 
We evaluated management’s sensitivity analyses
over asset retirement obligations, including the
effect of performing removal five years earlier than
scheduled.
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
311
Recognition of deferred tax asset related to the
 
US filing jurisdiction
Basis for the key audit matter
As at 31 December 2022, the Company has recognised
 
a previously
unrecognised deferred tax asset of USD 2,738 million
 
related to the US
filing jurisdiction, which requires convincing evidence
 
through future
taxable profit to support the probable realisation
 
of the deferred tax
asset against historical carry-forward tax losses.
 
Refer to Note 11 to
the Consolidated Financial Statements for the related
 
disclosures. As
described in Note 11, deferred tax assets are recognised based on the
expectation that sufficient taxable income will be available
 
through
reversal of taxable temporary differences or future taxable
 
income. The
future taxable income has to be considered probable
 
based on
business forecasts.
In addition to agreeing the historical losses to
 
supporting
documentation, auditing management’s estimate of the amount
 
of the
deferred tax asset is subjective because the estimation
 
requires
significant judgement, including the timing of reversals
 
of the deferred
tax liability and the availability of future profits
 
against which tax
deductions represented by the deferred tax asset
 
can be offset. In
addition, auditing management’s estimate of amount of the deferred
tax balances that are supported by the expectation
 
of future taxable
profits requires a high degree of judgement. Significant
 
assumptions
used in future taxable profits are commodity prices,
 
expected oil and
gas reserves and capital expenditures.
These significant assumptions are forward-looking and are
 
heightened
in complexity given the future demand and price uncertainty
 
due to
climate change and the energy transition. For more detail,
 
please refer
to the key audit matter related to the Impact of
 
climate change and
energy transition on the financial statements.
We consider the recognition of the deferred tax asset
 
related to the US
filing jurisdiction to be a key audit matter given
 
the significance of the
account on the balance sheet and the complexity and
 
uncertainty of
the estimates and assumptions used by management
 
in the estimation
of future taxable profits.
Our audit response
We obtained an understanding, evaluated the design, and
 
tested the
operating effectiveness of controls over the Company’s process
 
for the
recognition of the deferred tax asset related to the US
 
filing jurisdiction.
This included testing controls over the Company’s process
 
for tracking
tax loss carry-forwards, management’s review of assumptions
 
and
inputs to the calculations of future taxable profit and
 
scheduling of
reversal of the deferred tax liabilities.
In assessing the recognition and measurement of
 
the deferred taxes
we tested the completeness and accuracy of the amounts
 
recognised
as deferred tax asset by verifying tax loss carry-forwards
 
against
historical tax filings and assessing management’s determination
 
of the
expected timing of utilisation of the deferred
 
tax asset, including the
application of relevant tax laws to the utilisation of
 
tax losses. We also
evaluated management’s forecasted timing of the reversal of
 
taxable
temporary differences by considering the nature of the
 
temporary
differences and the relevant tax law. We involved our US tax
specialists to assist us in these procedures.
Our audit procedures performed over the significant
 
assumptions and
inputs included, among others, evaluation of the
 
methods and models
used in the calculation of future taxable profit. We compared
 
projected
capital expenditures, from which depreciation expense
 
is derived, and
expected reserve volumes used in the estimation
 
of the future taxable
profit to approved operator budgets or management
 
forecasts, and
also compared expected reserve volumes to external
 
evaluations when
available. In addition, we compared the forecast
 
to that used in other
areas of analysis, such as impairment or impairment
 
reversal
assessment, as applicable.
To test price assumptions, we evaluated management’s methodology
to determine future commodity prices and compared
 
such assumptions
to external benchmarks, among other procedures.
 
We evaluated
management’s methodology to factor climate-related matters into
 
their
determination of future commodity prices and carbon
 
costs
assumptions. For more detail, please refer to the
 
key audit matter
related to the Impact of climate change and energy
 
transition on the
financial statements.
We assessed management’s sensitivity analysis disclosed in Note
 
11
related to a reasonably possible change in commodity
 
prices.
 
 
 
 
 
312
 
Equinor, Annual Report on Form 20-F 2022
 
Recoverable amounts of production plants and
 
oil and gas assets including assets under development
Basis for the key audit matter
As at 31 December 2022, the Company has recognised
 
production
plants and oil and gas assets, including assets
 
under development, of
USD 40,493 million and USD 10,679 million, respectively, within
Property, plant and equipment. Refer to Note 14 to the Consolidated
Financial Statements for the related disclosures.
 
As described in Note
14, determining the recoverable amount of an asset
 
involves an
estimate of future cash flows, which is dependent
 
upon management’s
best estimate of the economic conditions that will
 
exist over the
asset’s useful life. The asset’s operational performance and external
factors have a significant impact on the estimated
 
future cash flows
and therefore, the recoverable amount of the asset.
Auditing management’s estimate of the recoverable amount
 
of
production plants and oil and gas assets is
 
complex and involves a
high degree of judgement. Significant assumptions
 
used in forecasting
future cash flows are future commodity prices, currency
 
exchange
rates, expected reserves, capital expenditures, and
 
the discount rate.
These significant assumptions are forward-looking and
 
can be
affected by future economic and market conditions, including
 
matters
related to climate change and energy transition.
 
For more detail,
please refer to the key audit matter related to the
 
Impact of climate
change and energy transition on the financial
 
statements.
Additionally, the treatment of tax in the estimation of the recoverable
amount is challenging, as the Company is subject to different
 
tax
structures that are inherently complex, particularly
 
in Norway.
We consider the determination of the recoverable amounts
 
of
production plants and oil and gas assets including
 
assets under
development to be a key audit matter given
 
the significance of the
accounts on the balance sheet and the complexity
 
and uncertainty of
the estimates and assumptions used by management
 
in the cash flow
models.
Our audit response
We obtained an understanding, evaluated the design, and
 
tested the
operating effectiveness of controls over the Company’s process
 
for
evaluating the recoverability of production plants
 
and oil and gas assets
including assets under development. This included
 
testing controls over
management’s review of assumptions and inputs to the
 
assessments of
impairment and impairment reversals.
Our audit procedures performed over the significant
 
assumptions and
inputs included, among others, evaluation of the
 
methods and models
used in the calculation of the recoverable amount.
 
We also evaluated
the relevant tax effects based on the local legislation
 
of the relevant
jurisdictions, particularly in Norway, and tested the clerical accuracy of
the models through independently recalculating the
 
value in use. We
involved valuation specialists to assist us with these
 
procedures. In
addition, we compared projected capital expenditures
 
to approved
operator budgets or management forecasts and compared
 
expected
reserve volumes to internal production forecasts and external
evaluations of expected reserves, in accordance with
 
the Company’s
internal procedures. For those assets previously impaired,
 
we
compared actual results to the forecasts used
 
in historical impairment
analyses. We also involved reserves specialists to assist
 
us with these
procedures.
To test price assumptions, we evaluated management’s methodology to
determine future commodity prices and compared such
 
assumptions to
external benchmarks, among other procedures. We involved
 
valuation
specialists to assist in evaluating the reasonableness
 
of the Company’s
assessment of currency exchange rates and the
 
discount rate, by
assessing the Company’s methodologies and key assumptions
 
used to
calculate the rates and by comparing those
 
rates with external
information.
We also evaluated management’s methodology to factor climate-related
matters into their determination of future commodity prices
 
and carbon
costs assumptions. For more detail, please refer
 
to the key audit matter
related to the Impact of climate change and energy
 
transition on the
financial statements.
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
313
Estimation of the asset retirement obligation
Basis for the key audit matter
As at 31 December 2022, the Company has recognised
 
a provision for
decommissioning and removal activities of USD 11,734 million
classified within Provisions and other liabilities. Refer
 
to Note 23 to the
Consolidated Financial Statements for disclosures. As described
 
in
Note 23, the appropriate estimates for such obligations
 
are based on
historical knowledge combined with knowledge of ongoing
technological developments, expectations about
 
future regulatory and
technological development and involve the application
 
of judgement
and an inherent risk of significant adjustments.
 
The estimated costs of
decommissioning and removal activities require revisions
 
due to
changes in current regulations and technology while
 
considering
relevant risks and uncertainties.
Auditing management’s estimate of the decommissioning and
 
removal
of offshore installations at the end of the production period
 
is complex
and involves a high degree of judgement. Determining
 
the provision for
such obligation involves application of considerable
 
judgement related
to the assumptions used in the estimate, the inherent
 
complexity and
uncertainty in estimating future costs, and the limited
 
historical
experience against which to benchmark estimates of
 
future costs.
Significant assumptions used in the estimate are
 
the discount rates
and the expected future costs, which include the underlying
assumptions norms and rates and time required
 
to decommission and
can vary considerably depending on the expected
 
removal complexity.
These significant assumptions are forward-looking and
 
can be affected
by future economic and market conditions, including matters
 
related to
climate change and energy transition. For more
 
detail, please refer to
the key audit matter related to the Impact of climate
 
change and
energy transition on the financial statements.
We consider the estimation of the asset retirement obligations
 
(ARO)
to be a key audit matter given the significance
 
of the related accounts
to the financial statements and the complexity and
 
uncertainty of the
assumptions used in the estimate.
Our audit response
We obtained an understanding, evaluated the design, and
 
tested the
operating effectiveness of controls over the Company’s process
 
to
calculate the present value of the estimated future decommissioning
and removal expenditures determined in accordance
 
with local
conditions and requirements. This includes controls related
 
to
management’s review of assumptions described above,
 
used in the
calculation of the ARO.
To test management’s estimation of the provision for decommissioning
and removal activities, our audit procedures included,
 
among others,
evaluating the completeness of the provision by
 
comparing significant
additions to property, plant and equipment to management’s
assessment of new ARO obligations recognized in the
 
period.
To assess the expected future costs, among other procedures, we
compared day rates for rigs, marine operations
 
and heavy lift vessels to
external market data or existing contracts. For time
 
required to
decommission, we compared the assumptions against
 
historical data
on a sample basis. We compared discount rates to external
 
market
data. With the support of our valuation specialists, we
 
evaluated the
methodology and models used by management to estimate
 
the ARO
and performed a sensitivity analysis on the significant assumptions.
 
In
addition, we recalculated the formulas in the models.
We also evaluated management’s methodology to factor climate-
related matters into their determination of the
 
timing of cessation of the
assets and the asset retirement obligations. For
 
more detail, please
refer to the key audit matter related to the Impact of
 
climate change
and energy transition on the financial statements.
314
 
Equinor, Annual Report on Form 20-F 2022
 
Other information
Other information consists of the information included
 
in the annual report other than the financial statements
 
and our auditor’s report thereon.
Management (the board of directors and Chief
 
Executive Officer) is responsible for the other information. Our
 
opinion on the financial
statements does not cover the other information,
 
and we do not express any form of assurance
 
conclusion thereon.
In connection with our audit of the financial statements,
 
our responsibility is to read the other information,
 
and, in doing so, consider whether
the board of directors’ report, the statement on
 
corporate governance, the statement on corporate
 
social responsibility and the report on
payments to government contain the information required
 
by applicable legal requirements and whether
 
the other information is materially
inconsistent with the financial statements or our
 
knowledge obtained in the audit, or otherwise
 
appears to be materially misstated. If, based on
the work we have performed, we conclude that
 
the other information is materially inconsistent with the
 
financial statements, there is a material
misstatement in this other information or that the
 
information required by applicable legal requirements
 
is not included in the board of directors’
report, the statement on corporate governance, the
 
statement on corporate social responsibility
 
or the payments to government report, we
 
are
required to report that fact.
We have nothing to report in this regard, and in our opinion,
 
the board of directors’ report, the statement
 
on corporate governance, the
statement on corporate social responsibility and the report
 
on payments to governments are consistent
 
with the financial statements and
contain the information required by applicable legal
 
requirements.
Responsibilities of management for the financial
 
statements
Management is responsible for the preparation and
 
fair presentation of the financial statements of
 
the Company in accordance with simplified
application of international accounting standards according
 
to section 3-9 of the Norwegian Accounting Act
 
and of the consolidated financial
statements of the Group in accordance with International
 
Financial Reporting Standards as adopted by
 
the EU, and for such internal control as
management determines is necessary to enable the
 
preparation of financial statements that are free
 
from material misstatement, whether due
to fraud or error.
In preparing the financial statements, management is responsible
 
for assessing the Company’s and the Group’s ability to continue as a
 
going
concern, disclosing, as applicable, matters related
 
to going concern and using the going concern
 
basis of accounting unless management
either intends to liquidate the Company or the Group,
 
or to cease operations, or has no realistic
 
alternative but to do so.
Auditor’s responsibilities for the audit of the
 
financial statements
Our objectives are to obtain reasonable assurance about
 
whether the financial statements as a whole
 
are free from material misstatement,
whether due to fraud or error, and to issue an auditor’s report
 
that includes our opinion. Reasonable assurance
 
is a high level of assurance,
but is not a guarantee that an audit conducted
 
in accordance with ISAs will always detect a
 
material misstatement when it exists.
Misstatements can arise from fraud or error
 
and are considered material if, individually or
 
in the aggregate, they could reasonably be expected
to influence the economic decisions of users taken
 
on the basis of these financial statements.
As part of an audit in accordance with ISAs,
 
we exercise professional judgment and maintain
 
professional scepticism throughout the audit. We
also:
●
 
Identify and assess the risks of material misstatement
 
of the financial statements, whether due to
 
fraud or error, design and perform
audit procedures responsive to those risks, and
 
obtain audit evidence that is sufficient and appropriate
 
to provide a basis for our
opinion. The risk of not detecting a material
 
misstatement resulting from fraud is higher than
 
for one resulting from error, as fraud
may involve collusion, forgery, intentional omissions, misrepresentations, or the override
 
of internal control.
●
 
Obtain an understanding of internal control relevant
 
to the audit in order to design audit procedures
 
that are appropriate in the
circumstances, but not for the purpose of expressing
 
an opinion on the effectiveness of the Company’s and
 
the Group’s internal
control.
●
 
Evaluate the appropriateness of accounting policies
 
used and the reasonableness of accounting
 
estimates and related disclosures
made by management.
 
●
 
Conclude on the appropriateness of management’s use of
 
the going concern basis of accounting and,
 
based on the audit evidence
obtained, whether a material uncertainty exists
 
related to events or conditions that may
 
cast significant doubt on the Company’s and
the Group’s ability to continue as a going concern.
 
If we conclude that a material uncertainty exists,
 
we are required to draw
attention in our auditor’s report to the
 
related disclosures in the financial statements or, if such disclosures are
 
inadequate, to modify
our opinion. Our conclusions are based on
 
the audit evidence obtained up to the date
 
of our auditor’s report. However, future events
or conditions may cause the Company and the Group
 
to cease to continue as a going concern.
●
 
Evaluate the overall presentation, structure and content
 
of the financial statements, including the
 
disclosures, and whether the
financial statements represent the underlying transactions
 
and events in a manner that achieves fair presentation.
●
 
Obtain sufficient appropriate audit evidence regarding the financial
 
information of the entities or business activities
 
within the Group
to express an opinion on the consolidated financial
 
statements. We are responsible for the direction, supervision
 
and performance of
the group audit. We remain solely responsible for our audit
 
opinion.
We communicate with the board of directors regarding,
 
among other matters, the planned scope and
 
timing of the audit and significant audit
findings, including any significant deficiencies in internal
 
control that we identify during our audit.
We also provide the audit committee with a statement
 
that we have complied with relevant ethical
 
requirements regarding independence, and
to communicate with them all relationships and other
 
matters that may reasonably be thought to
 
bear on our independence, and where
applicable, related safeguards.
Equinor, Annual Report on Form 20-F 2022
 
315
From the matters communicated with the board
 
of directors, we determine those matters that were
 
of most significance in the audit of the
financial statements of the current period and are
 
therefore the key audit matters. We describe these
 
matters in our auditor’s report unless law
or regulation precludes public disclosure about the
 
matter or when, in extremely rare circumstances,
 
we determine that a matter should not be
communicated in our report because the adverse
 
consequences of doing so would reasonably be expected
 
to outweigh the public interest
benefits of such communication.
Report on other legal and regulatory requirement
Report on compliance with regulation on European
 
Single Electronic Format (ESEF)
Opinion
As part of the audit of the financial statements of
 
Equinor ASA we have performed an assurance
 
engagement to obtain reasonable assurance
about whether the financial statements included in
 
the annual report, with the file name eqnr20221231NO.zip,
 
have been prepared, in all
material respects, in compliance with the requirements of
 
the Commission Delegated Regulation (EU)
 
2019/815 on the European Single
Electronic Format (ESEF Regulation) and regulation
 
pursuant to Section 5-5 of the Norwegian
 
Securities Trading Act, which includes
requirements related to the preparation of the
 
annual report in XHTML format and iXBRL
 
tagging of the consolidated financial statements.
In our opinion, the financial statements, included in
 
the annual report, have been prepared, in all
 
material respects, in compliance with the
ESEF Regulation.
Management’s responsibilities
Management is responsible for the preparation of
 
the annual report in compliance with the ESEF
 
Regulation. This responsibility comprises an
adequate process and such internal control as
 
management determines is necessary.
Auditor’s responsibilities
Our responsibility, based on audit evidence obtained, is to express an opinion
 
on whether, in all material respects, the financial statements
included in the annual report have been prepared
 
in accordance with the ESEF Regulation. We conduct
 
our work in accordance with the
International Standard for Assurance Engagements (ISAE) 3000
 
– “Assurance engagements other than audits
 
or reviews of historical financial
information”. The standard requires us to plan and
 
perform procedures to obtain reasonable assurance
 
about whether the financial statements
included in the annual report have been prepared
 
in accordance with the ESEF Regulation.
As part of our work, we perform procedures
 
to obtain an understanding of the company’s processes for
 
preparing the financial statements in
accordance with the ESEF Regulation. We test whether
 
the financial statements are presented in XHTML-format.
 
We evaluate the
completeness and accuracy of the iXBRL tagging
 
of the consolidated financial statements and assess
 
management’s use of judgement. Our
procedures include reconciliation of the iXBRL tagged
 
data with the audited financial statements in
 
human-readable format. We believe that
the evidence we have obtained is sufficient and appropriate
 
to provide a basis for our opinion.
Stavanger, 14 March 2023
ERNST & YOUNG AS
Tor Inge Skjellevik
State Authorised Public Accountant (Norway)
(This translation from Norwegian has been prepared
 
for information purposes only.)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
316
 
Equinor, Annual Report on Form 20-F 2022
 
Independent accountant’s assurance report
To the Annual Shareholders' Meeting of Equinor ASA
Scope
We have been engaged by Equinor ASA to perform
 
an assurance engagement, that will give
 
●
 
Limited assurance, as defined by International
 
Standards on Assurance Engagements, to report on
 
Equinor ASA ’s sustainability
reporting as defined and specified in the Equinor
 
ASA’s GRI Index (see the document GRI Index 2022 on
https://www.equinor.com/sustainability/reporting) (the “Subject Matter for limited assurance”) as of
 
31 December 2022 and for the
period from 1 January to 31 December 2022.
●
 
Reasonable assurance, as defined by International
 
Standards on Assurance Engagements, to report on
 
Equinor ASA’s
sustainability reporting as defined and specified
 
in Table 1, which Equinor ASA has defined in the Company's GRI index (see
 
the
document GRI index 2022 on https://www.equinor.com/sustainability/reporting) (the “Subject
 
Matter for reasonable assurance”) as at
31 December 2022 and for the period from
 
1 January 2022 to 31 December 2022.
Table 1: Disclosure description and boundary as defined in the GRI index
Disclosure description:
Boundary:
Renewable energy production
Equity basis
Renewable installed capacity
Equity basis
Scope 1 GHG emissions
Operational control
CO2 emissions (Scope 1)
Operational control
CH4 emissions
Operational control
Scope 2 GHG emissions (location based)
Operational control
Scope 2 GHG emissions (market based)
Operational control
Number of oil spills
 
Operational control
Volume of oil spills
Operational control
Oil and gas leakages with a leakage rate
 
of 0.1kg per second or more
[KPI]
Operational control
GRI 403-9 (This includes reporting on the KPIs
 
“Total serious incident
frequency (SIF) [KPI]”, “Actual SIF”, Total recordable injury frequency
(TRIF) [KPI]”, “Employee TRIF”, “Contractor TRIF”,
 
“Total fatalities”,
“Employees’ fatalities”, “Contractors’ fatalities”)
Operational control
We did not perform assurance procedures over section 2.2.2
 
“Portfolio robustness” in the Equinor 2022
 
Integrated Annual Report, or on
Equinor’s reporting on Greenhouse gas (“GHG”)
 
emissions at individual field level presented
 
in Equinor Sustainability Data hub.
 
Furthermore, we did not perform assurance procedures
 
on the historical information presented for 2016,
 
2017 and 2018 referred to by Equinor
ASA in the Equinor 2022 Integrated Annual Report.
Other than as described in the first paragraph,
 
which sets out the scope of our engagement,
 
we did not perform assurance procedures on the
remaining information included in the Equinor 2022
 
Integrated Annual report, and accordingly, we do not express an opinion
 
on this
information.
 
Criteria applied by Equinor ASA
In preparing the Subject Matter for limited assurance
 
and Subject Matter for reasonable assurance (the
 
”Subject Matters”), Equinor ASA
applied the relevant criteria from the Global Reporting
 
Initiative (GRI) sustainability reporting standards
 
as well as own defined criteria (the
“Criteria”). The Criteria can be accessed at globalreporting.org
 
and Equinor Sustainability Data Hub and are
 
available to the public. Such
Equinor, Annual Report on Form 20-F 2022
 
317
Criteria were specifically designed for companies and
 
other organizations that want to report
 
their sustainability impacts in a consistent and
credible way. As a result, the information may not be suitable for another purpose.
Equinor ASA’s responsibilities
The Board of Directors and management are responsible
 
for selecting the Criteria, and for presenting
 
the Subject Matters in accordance with
the Criteria, in all material respects. This responsibility
 
includes establishing and maintaining internal
 
controls, maintaining adequate records
and making estimates that are relevant to the preparation
 
of the Subject Matters, such that they are
 
free from material misstatement, whether
due to fraud or error.
EY’s responsibilities – limited assurance engagement
Our responsibility is to express an opinion on the
 
presentation of the Subject Matter for reasonable
 
assurance based on the evidence we have
obtained.
 
We conducted our engagement in accordance with
the International Standard for Assurance Engagements
 
Other Than Audits or Reviews of
Historical Financial Information (‘ISAE 3000 (Revised)’).
 
This standard requires that we plan and perform
 
our engagement to obtain
reasonable assurance about whether, in all material respects, the Subject
 
Matter for reasonable assurance is presented in accordance
 
with
the Criteria, and to issue a report. The nature,
 
timing, and extent of the procedures selected depend
 
on our judgment, including an
assessment of the risk of material misstatement, whether
 
due to fraud or error.
 
We believe that the evidence obtained is sufficient and appropriate
 
to provide a basis for our reasonable assurance
 
opinion.
EY’s responsibilities – reasonable assurance engagement
Our responsibility is to express an opinion on the
 
presentation of the Subject Matter for reasonable
 
assurance based on the evidence we have
obtained.
 
We conducted our engagement in accordance with
the International Standard for Assurance Engagements
 
Other Than Audits or Reviews of
Historical Financial Information (‘ISAE 3000 (Revised)’)
. This standard requires that we plan and
 
perform our engagement to obtain
reasonable assurance about whether, in all material respects, the Subject
 
Matter for reasonable assurance is presented in accordance
 
with
the Criteria, and to issue a report. The nature,
 
timing, and extent of the procedures selected depend
 
on our judgment, including an
assessment of the risk of material misstatement, whether
 
due to fraud or error.
 
We believe that the evidence obtained is sufficient and appropriate
 
to provide a basis for our reasonable assurance
 
opinion.
Our Independence and Quality Control
We have maintained our independence in accordance with
 
the requirements in relevant laws and regulations
 
in Norway and the Code of
Ethics for Professional Accountants issued by the
 
International Ethics Standards Board for Accountants.
 
Our firm applies
ISQC 1, Quality
Control for Firms that Perform Audits and Reviews
 
of Financial Statements, and Other Assurance and Related
 
Services Engagements
, and
accordingly maintains a comprehensive system of quality
 
control including documented policies and procedures
 
regarding compliance with
ethical requirements, professional standards and applicable
 
legal and regulatory requirements.
Description of procedures performed
This engagement is designed to express a) limited
 
assurance on the Subject Matter for limited
 
assurance and b) reasonable assurance on the
Subject Matter for reasonable assurance.
 
The GHG quantification process used in preparing
 
the reporting is subject to scientific uncertainty, which arises because of incomplete
scientific knowledge about the measurement of GHGs,
 
including CO2 and CH4. Additionally, GHG emissions are subject to estimation
 
and
measurement uncertainty resulting from the calculation
 
process used to quantify emissions within the
 
bounds of existing scientific knowledge.
Our verification of these disclosures relates to the
 
criteria for estimation set by local authorities.
 
a)
 
Procedures performed to express a statement with limited
 
assurance
Procedures performed in a limited assurance engagement
 
vary in nature and timing from, and are
 
less in extent than for, a reasonable
assurance engagement. Consequently, the level of assurance obtained in a limited
 
assurance engagement is substantially lower
 
than the
assurance that would have been obtained if a reasonable
 
assurance engagement had been performed.
 
Our procedures were designed to
obtain a limited level of assurance on which to base
 
our conclusion and do not provide all the
 
evidence that would be required to provide a
reasonable level of assurance.
Although we considered the effectiveness of management’s internal
 
controls when determining the nature and extent of
 
our procedures, our
assurance engagement was not designed to provide
 
assurance on internal controls. Our procedures
 
did not include testing controls or
performing procedures relating to checking aggregation
 
or calculation of data within IT systems.
A limited assurance engagement consists of making
 
enquiries, primarily of persons responsible
 
for preparing the Subject Matter for limited
assurance and related information and applying
 
analytical and other appropriate procedures.
 
Our procedures included:
 
●
 
Conducted interviews with key personnel to understand
 
the business and the reporting process
●
 
Conducted interviews with key personnel to understand
 
the process for collecting, collating and reporting
 
the Subject Matter for
limited assurance during the reporting period
318
 
Equinor, Annual Report on Form 20-F 2022
 
●
 
Checked on a sample basis the calculation Criteria against
 
the methodologies outlined in the Criteria
 
●
 
Performed analytical review procedures of the data
●
 
Identified and tested the assumptions supporting the
 
calculations
●
 
Tested, on a sample basis, the underlying source information
 
●
 
Checked that the presentation requirements outlined
 
in the Criteria
 
We believe that our procedures provide us with an
 
adequate basis for our conclusion. We also performed
 
such other procedures as we
considered necessary in the circumstances.
b)
 
Procedures performed to express a statement with reasonable
 
assurance
Procedures to obtain a reasonable assurance
 
level include examining, on a test basis, evidence
 
supporting the quantitative and qualitative
information.
To obtain reasonable assurance our procedures included:
●
 
Conducted interviews with key personnel to understand
 
the business and the reporting process
●
 
Conducted interviews with key personnel to understand
 
the process for collecting, collating and reporting
 
the Subject Matter for
reasonable assurance during the reporting period
●
 
Checked on a sample basis the calculation Criteria against
 
the methodologies outlined in the Criteria
 
●
 
Performed analytical review procedures of the data
●
 
Identified and tested the assumptions supporting the
 
calculations
●
 
Tested, on a sample basis, the underlying source information
 
●
 
Checked that the presentation requirements outlined
 
in the Criteria
 
●
 
Performed digital site visits and interviews with Company’s personnel
 
at a sample of locations in order to gather
 
and review
underlying data and assess the implementation
 
of the processes and controls related to the
 
preparation of the selected safety and
environmental KPIs
●
 
Recalculating of safety and climate disclosures presented
 
in Table 1 presented above, and assessing the reasonableness of the
estimates made by the Equinor
 
We believe that our procedures provide us with an
 
adequate basis for our opinion. We also performed
 
such other procedures as we
considered necessary in the circumstances.
Limited assurance conclusion
Based on our procedures and the evidence obtained,
 
we are not aware of any material modifications
 
that should be made to the Subject
Matter for limited assurance as of 31 December 2022
 
and for the period from 1 January 2022
 
to 31 December 2022 in order for it to be
 
in
accordance with the Criteria.
Reasonable assurance opinion
In our opinion the Subject Matter for reasonable assurance
 
as at 31 December 2022 and for the period
 
from 1 January 2022 to 31 December
2022 is presented, in all material respects, in accordance
 
with the Criteria.
Stavanger, 14 March 2023
ERNST & YOUNG AS
Tor Inge Skjellevik
State Authorised Public Accountant (Norway)
(This translation from Norwegian has been prepared
 
for information purposes only.)
Equinor, Annual Report on Form 20-F 2022
 
319
5.8 Use and reconciliation of non-GAAP financial measures
Since 2007, Equinor has been preparing its audited consolidated financial statements in accordance with
 
International Financial
Reporting Standards (IFRS) as adopted by the European Union (EU) and as issued by the International
 
Accounting Standards Board.
IFRS has been applied consistently to all periods presented in the 2022 Consolidated financial statements.
Non-GAAP financial measures are defined as numerical measures that either exclude
 
or include amounts that are not excluded or
included in the comparable measures calculated and presented in accordance with generally accepted
 
accounting principles: (i.e,
IFRS in the case of Equinor). The following financial measures may be considered non-GAAP
 
financial measures:
a)
 
Net debt to capital employed ratio, Net debt to capital employed ratio adjusted, including lease
 
liabilities and Net debt to capital
employed ratio adjusted
b)
 
Return on average capital employed (ROACE)
c)
 
Organic capital expenditures
d)
 
Free cashflow
e)
 
Adjusted earnings and adjusted earnings after tax
f)
 
Total shareholder return (TSR)
g)
 
Gross capital expenditure (gross capex)
a) Net debt to capital employed ratio
In Equinor’s view, net debt ratio provides a more informative picture of Equinor’s financial strength than gross interest-bearing
 
financial
debt. Three different net debt ratios are provided below; 1) net debt to capital employed ratio, 2) net debt
 
to capital employed ratio
adjusted, including lease liabilities, and 3) net debt to capital employed ratio adjusted.
The calculation is based on gross interest-bearing financial debt in the balance sheet and excludes
 
cash, cash equivalents and
current financial investments. Certain adjustments are made, e.g. collateral deposits classified
 
as cash and cash equivalents in the
Consolidated balance sheet are considered non-cash in the non-GAAP
 
calculations. The financial investments held in Equinor
Insurance AS are excluded in the non-GAAP calculations as they are deemed restricted. These two
 
adjustments increase net debt
and give a more prudent definition of the net debt to capital employed ratio than if the
 
IFRS based definition was to be used. Following
implementation of IFRS16 Equinor presents a “net debt to capital employed adjusted” excluding lease liabilities
 
from the gross
interest-bearing debt. Net interest-bearing debt adjusted for these items is included in the
 
average capital employed. The table below
reconciles the net interest-bearing debt adjusted, the capital employed and the net debt
 
to capital employed adjusted ratio with the
most directly comparable financial measure or measures calculated in accordance with IFRS.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
320
 
Equinor, Annual Report on Form 20-F 2022
 
Calculation of capital employed and net debt to capital
 
employed ratio
For the year ended 31 December
(in USD million)
2022
2021
2020
Shareholders' equity
53,988
39,010
33,873
Non-controlling interests
1
14
19
Total equity
A
53,989
39,024
33,892
Current finance debt and lease liabilities
5,617
6,386
5,777
Non-current finance debt and lease liabilities
26,551
29,854
32,338
Gross interest-bearing debt
B
32,168
36,239
38,115
Cash and cash equivalents
15,579
14,126
6,757
Current financial investments
29,876
21,246
11,865
Cash and cash equivalents and current financial investment
C
45,455
35,372
18,621
Net interest-bearing debt before adjustments
B1 = B-C
(13,288)
867
19,493
Other interest-bearing elements
 
1)
6,538
2,369
627
Net interest-bearing debt adjusted, including lease
 
liabilities
B2
(6,750)
3,236
20,121
Lease liabilities
3,668
3,562
4,405
Net interest-bearing debt adjusted
B3
(10,417)
(326)
15,716
Calculation of capital employed:
Capital employed
A+B1
40,701
39,891
53,385
Capital employed adjusted, including lease liabilities
A+B2
47,239
42,259
54,012
Capital employed adjusted
A+B3
43,571
38,697
49,608
Calculated net debt to capital employed
Net debt to capital employed
(B1)/(A+B1)
(32.6%)
2.2%
36.5%
Net debt to capital employed adjusted, including
 
lease liabilities
(B2)/(A+B2)
(14.3%)
7.7%
37.3%
Net debt to capital employed adjusted
(B3)/(A+B3)
(23.9%)
(0.8%)
31.7%
1)
Other interest-bearing elements are cash and
 
cash equivalents adjustments regarding collateral
 
deposits classified as cash and cash
 
equivalents in the Consolidated balance sheet but
 
considered as non-cash in the non-GAAP calculations
 
as well as financial investments
in Equinor Insurance AS classified as current financial
 
investments.
b) Return on average capital employed (ROACE)
ROACE is defined as adjusted earnings after tax divided by average capital employed adjusted. For
 
a reconciliation for adjusted
earnings after tax, see e) later in this section. Average capital employed adjusted at 31 December 2022 is calculated as the
 
average
of the capital employed adjusted at 31 December 2022 and at 31 December 2021 as presented in
 
the table Calculation of capital
employed and net debt to capital employed ratio section a).
Equinor uses ROACE to measure the return on capital employed adjusted, regardless of whether
 
the financing is through equity or
debt. This measure provides useful information for both the group and investors
 
about performance during the period under
evaluation. The use of ROACE should not be viewed as an alternative to income before financial
 
items, income taxes and minority
interest, or to net income, which are measures calculated in accordance with IFRS or ratios based
 
on these figures.
Forward-looking ROACE included in this report is not reconcilable to its most directly comparable
 
IFRS measure without unreasonable
efforts, because the amounts excluded from IFRS measures used to determine ROACE cannot be predicted with reasonable
certainty.
Calculated ROACE based on IFRS
31 December
(in USD million, except percentages)
2022
2021
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
321
Net income/(loss)
A
28,744
8,576
Average total equity
1
46,506
36,458
Average current finance debt and lease liabilities
6,001
6,081
Average non-current finance debt and lease liabilities
28,202
31,096
- Average cash and cash equivalents
(14,853)
(10,442)
- Average current financial investments
(25,561)
(16,555)
Average net-interest bearing debt
2
(6,210)
10,180
Average capital employed
B = 1+2
40,296
46,638
Calculated ROACE based on Net income/loss and
 
capital employed
A/B
71.3 %
18.4 %
Calculated ROACE based on Adjusted earnings after
 
tax and capital employed adjusted
 
31 December
(in USD million, except percentages)
2022
2021
Adjusted earnings after tax
A
22,691
10,042
Average capital employed adjusted
B
41,134
44,153
Calculated ROACE based on Adjusted earnings
 
after tax and capital employed adjusted
A/B
55.2%
22.7%
c) Organic capital expenditures
Capital expenditures, defined as Additions to PP&E, intangibles and equity accounted investments
 
in note 5 Segments to the
Consolidated financial statements, amounted to USD 10.0 billion in 2022.
Organic capital expenditures are capital expenditures excluding acquisitions, recognised lease assets
 
(RoU assets) and other
investments with significant different cash flow patterns. Organic capital expenditure is a measure which Equinor believes
 
gives
relevant information about Equinor’s investments in maintenance and development
 
of the company’s assets.
In 2022, a total of USD 1.9 billion was excluded in the organic capital expenditures. Among items
 
excluded were additions of Right of
Use (RoU) assets related to leases and acquisition of Triton Power in UK, certain Statfjord licence shares and US based
 
battery
storage developer East Point Energy, resulting in organic capital expenditure of USD 8.1 billion.
In 2021, a total of USD 0.4 billion was excluded in the organic capital expenditures. Among items
 
excluded were acquisition of 100%
interest in Polish onshore renewables developer Wento and additions of Right of Use (RoU) assets
 
related to leases, resulting in
organic capital expenditure of USD 8.1 billion.
d) Free cash flow
Free cash flow represents, and is used by management to evaluate, cash generated from
 
operational and investing activities available
for debt servicing and distribution to shareholders. However, free cash flow is not a measure of our liquidity under IFRS and should
not be considered in isolation or as a substitute for an analysis of our results as reported in this
 
report. Our definition of free cash flow
is limited and does not represent residual cash flows available for discretionary expenditures.
The following table provides a reconciliation of Free cash flow to Cash flows provided by
 
operating activities before taxes paid and
working capital items, the most directly comparable financial measure presented in accordance
 
with IFRS, as of the dates indicated:
Free cash flow
(in USD billion)
2022
2021
Cash flows provided by operating activities before
 
taxes paid and working capital items
 
83.6
 
 
42.0
 
Taxes paid
 
(43.9)
 
(8.6)
 
 
 
 
 
 
 
 
 
 
 
322
 
Equinor, Annual Report on Form 20-F 2022
 
Capital expenditures and investments
 
(8.6)
 
(8.2)
Proceeds from sale of assets and businesses
 
1.0
 
 
1.9
 
Free cash flow before capital distribution
 
32.1
 
 
27.1
 
Dividend paid
 
(5.4)
 
(1.8)
Share buy-back
 
(3.3)
 
(0.3)
Free cash flow
 
23.4
 
 
25.0
 
e) Adjusted earnings and adjusted earnings after tax
Management considers adjusted earnings and adjusted earnings after tax together with other non-GAAP
 
financial measures as
defined below, to provide an indication of the underlying operational and financial performance in the period (excluding financing) by
adjusting by items that are not well correlated to Equinor’s operating performance, and therefore
 
better facilitate comparisons between
periods.
Adjusted earnings
are based on net operating income/(loss) and adjusts for certain items affecting the income for the period in
 
order
to separate out effects that management considers may not be well correlated to Equinor’s
 
underlying operational performance in the
individual reporting period. Management considers adjusted earnings to be a supplemental
 
measure to Equinor’s IFRS measures,
which provides an indication of Equinor’s underlying operational performance in the
 
period and facilitates an alternative understanding
of operational trends between the periods. Adjusted earnings include adjusted revenues and other income, adjusted
 
purchases,
adjusted operating expenses and selling, general and administrative expenses, adjusted depreciation expenses
 
and adjusted
exploration expenses.
 
Adjusted earnings adjusts for the following items:
●
Changes in fair value of derivatives:
 
Certain gas contracts are, due to pricing or delivery conditions, deemed to contain
embedded derivatives, required to be carried at fair value. Also, certain transactions related to
 
historical divestments include
contingent consideration, are carried at fair value. The accounting impacts of changes in fair
 
value of the aforementioned are
excluded from adjusted earnings. In addition, adjustments are also made for changes in the unrealised
 
fair value of derivatives
related to some natural gas trading contracts. Due to the nature of these gas sales contracts, these
 
are classified as financial
derivatives to be measured at fair value at the balance sheet date. Unrealised gains and losses
 
on these contracts reflect the
value of the difference between current market gas prices and the actual prices to be realised under the gas sales
 
contracts. Only
realised gains and losses on these contracts are reflected in adjusted earnings. This presentation best reflects
 
the underlying
performance of the business as it replaces the effect of temporary timing differences associated with the re-measurements of the
derivatives to fair value at the balance sheet date with actual realised gains and losses for the
 
period
●
Periodisation of inventory hedging effect:
Commercial storage is hedged in the paper market and is accounted for using the
lower of cost or market price. If market prices increase above cost price, the inventory will
 
not reflect this increase in value. There
will be a loss on the derivative hedging the inventory since the derivatives always reflect changes in the market
 
price. An
adjustment is made to reflect the unrealised market increase of the commercial storage. As
 
a result, loss on derivatives is
matched by a similar adjustment for the exposure being managed. If market prices decrease below
 
cost price, the write-down of
the inventory and the derivative effect in the IFRS income statement will offset each other and no adjustment is made
●
Over/underlift
: Over/underlift is accounted for using the sales method and therefore revenues were reflected
 
in the period the
product was sold rather than in the period it was produced. The over/underlift position
 
depended on a number of factors related to
our lifting programme and the way it corresponded to our entitlement share
 
of production. The effect on income for the period is
therefore adjusted, to show estimated revenues and associated costs based upon the production
 
for the period to reflect
operational performance and comparability with peers.
●
The
operational storage
is not hedged and is not part of the trading portfolio. Cost of goods sold is measured
 
based on the
FIFO (first-in, first-out) method, and includes realised gains or losses that arise due to
 
changes in market prices. These gains or
losses will fluctuate from one period to another and are not considered part of the underlying
 
operations for the period
●
Impairment and reversal of impairment
are excluded from adjusted earnings since they affect the economics of an asset for
the lifetime of that asset, not only the period in which it is impaired or the impairment
 
is reversed. Impairment and reversal of
impairment can impact both the exploration expenses and the depreciation, amortisation and net impairments line
 
items
●
Gain or loss from sales of assets
is eliminated from the measure since the gain or loss does not give an indication
 
of future
performance or periodic performance; such a gain or loss is related to the cumulative value creation
 
from the time the asset is
acquired until it is sold
●
Eliminations (Internal unrealised profit on inventories:):
Volumes derived from equity oil inventory will vary depending on
several factors and inventory strategies, i.e. level of crude oil in inventory, equity oil used in the refining process and level of in-
transit cargoes. Internal profit related to volumes sold between entities within the group, and still in inventory
 
at period end, is
eliminated according to IFRS (write down to production cost). The proportion of realised versus unrealised
 
gain will fluctuate from
one period to another due to inventory strategies and consequently impact net operating
 
income/(loss). Write-down to production
cost is not assessed to be a part of the underlying operational performance, and elimination
 
of internal profit related to equity
volumes is excluded in adjusted earnings
●
Other items of income and expense
are adjusted when the impacts on income in the period are not reflective of Equinor’s
underlying operational performance in the reporting period. Such items may be unusual
 
or infrequent transactions but they may
Equinor, Annual Report on Form 20-F 2022
 
323
also include transactions that are significant which would not necessarily qualify as either
 
unusual or infrequent. However, other
items adjusted do not constitute normal, recurring income and operating expenses for the company. Other items are carefully
assessed and can include transactions such as provisions related to reorganisation, early retirement,
 
etc.
●
Change in accounting policy
 
are adjusted when the impacts on income in the period are unusual or infrequent,
 
and not
reflective of Equinor’s underlying operational performance in the reporting
 
period
Adjusted earnings after tax
– equals the sum of net operating income/(loss) less income tax in reporting segments and adjustments
to operating income taking the applicable marginal tax into consideration. Adjusted earnings after
 
tax excludes net financial items and
the associated tax effects on net financial items. It is based on adjusted earnings less the tax effects on all elements
 
included in
adjusted earnings (or calculated tax on operating income and on each of the adjusting items
 
using an estimated marginal tax rate). In
addition, tax effect related to tax exposure items not related to the individual reporting period is excluded from
 
adjusted earnings after
tax. Management considers adjusted earnings after tax, which reflects a normalised tax charge
 
associated with its operational
performance excluding the impact of financing, to be a supplemental measure to Equinor’s
 
net income. Certain net USD denominated
financial positions are held by group companies that have a USD functional currency that is different from the currency in which
 
the
taxable income is measured. As currency exchange rates change between periods, the basis
 
for measuring net financial items for
IFRS will change disproportionally with taxable income which includes exchange gains and losses
 
from translating the net USD
denominated financial positions into the currency of the applicable tax return. Therefore, the
 
effective tax rate may be significantly
higher or lower than the statutory tax rate for any given period. Adjusted taxes included
 
in adjusted earnings after tax should not be
considered indicative of the amount of current or total tax expense (or taxes payable)
 
for the period.
Adjusted earnings and adjusted earnings after tax should be considered additional measures rather
 
than substitutes for net operating
income/(loss) and net income/(loss), which are the most directly comparable IFRS measures. There
 
are material limitations
associated with the use of adjusted earnings and adjusted earnings after tax compared with the
 
IFRS measures as such non-GAAP
measures do not include all the items of revenues/gains or expenses/losses of Equinor that
 
are needed to evaluate its profitability on
an overall basis. Adjusted earnings and adjusted earnings after tax are only intended to be
 
indicative of the underlying developments
in trends of our on-going operations for the production, manufacturing and marketing of our
 
products and exclude pre-and post-tax
impacts of net financial items. Equinor reflects such underlying development in our operations by eliminating
 
the effects of certain
items that may not be directly associated with the period's operations or financing. However, for that reason, adjusted earnings and
adjusted earnings after tax are not complete measures of profitability. These measures should therefore not be used in isolation.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
324
 
Equinor, Annual Report on Form 20-F 2022
 
Items impacting net operating income/(loss)
in the full year of 2022
Equinor
group
E&P
Norway
E&P
Internation
al
E&P USA
MMP
REN
Other
(in USD million)
Total revenues and other income
 
150,806
 
 
75,930
 
 
7,431
 
 
5,523
 
 
148,105
 
 
185
 
(86,367)
Adjusting items
 
(896)
 
(487)
 
185
 
 
-
 
 
(506)
 
(110)
 
22
 
Changes in fair value of derivatives
 
(207)
 
(263)
 
205
 
 
-
 
 
(149)
 
-
 
 
-
 
Periodisation of inventory hedging effect
 
(349)
 
-
 
 
-
 
 
-
 
 
(349)
 
-
 
 
-
 
Impairment from associated companies
 
1
 
 
-
 
 
-
 
 
-
 
 
-
 
 
1
 
 
-
 
Over-/underlift
 
510
 
 
507
 
 
3
 
 
-
 
 
-
 
 
-
 
 
-
 
Other adjustments
1)
 
(0)
 
-
 
 
(22)
 
-
 
 
-
 
 
-
 
 
22
 
Gain/loss on sale of assets
 
(850)
 
(731)
 
-
 
 
-
 
 
(9)
 
(111)
 
(0)
Adjusted total revenues and other income
 
149,910
 
 
75,443
 
 
7,616
 
 
5,523
 
 
147,599
 
 
75
 
(86,345)
Purchases [net of inventory variation]
 
(53,806)
 
0
 
 
(116)
 
(0)
 
(139,916)
 
-
 
 
86,227
 
Adjusting items
 
(610)
 
-
 
 
-
 
 
-
 
 
(33)
 
-
 
 
(577)
Operational storage effects
 
(33)
 
-
 
 
-
 
 
-
 
 
(33)
 
-
 
 
-
 
Eliminations
 
(577)
 
-
 
 
-
 
 
-
 
 
-
 
 
-
 
 
(577)
Adjusted purchases [net of inventory variation]
 
(54,415)
 
0
 
 
(116)
 
(0)
 
(139,949)
 
-
 
 
85,650
 
Operating and administrative expenses
 
 
(10,594)
 
(3,782)
 
(1,698)
 
(938)
 
(4,591)
 
(265)
 
681
 
Adjusting items
 
64
 
 
(54)
 
22
 
 
6
 
 
75
 
 
10
 
 
5
 
Over-/underlift
 
(41)
 
(54)
 
13
 
 
-
 
 
-
 
 
-
 
 
-
 
Other adjustments
 
7
 
 
-
 
 
2
 
 
-
 
 
-
 
 
-
 
 
5
 
Gain/loss on sale of assets
 
23
 
 
-
 
 
7
 
 
6
 
 
-
 
 
10
 
 
-
 
Provisions
 
75
 
 
-
 
 
-
 
 
-
 
 
75
 
 
-
 
 
-
 
Adjusted operating and administrative expenses
 
 
(10,530)
 
(3,836)
 
(1,675)
 
(933)
 
(4,516)
 
(255)
 
686
 
Depreciation, amortisation and net impairments
 
(6,391)
 
(4,167)
 
(1,731)
 
(361)
 
14
 
 
(4)
 
(142)
Adjusting items
 
(2,488)
 
(819)
 
286
 
 
(1,060)
 
(895)
 
-
 
 
-
 
Impairment
 
1,111
 
 
3
 
 
1,033
 
 
-
 
 
75
 
 
-
 
 
-
 
Reversal of impairment
 
(3,598)
 
(821)
 
(747)
 
(1,060)
 
(970)
 
-
 
 
-
 
Adjusted depreciation, amortisation and net
impairments
 
(8,879)
 
(4,986)
 
(1,445)
 
(1,422)
 
(881)
 
(4)
 
(142)
Exploration expenses
 
(1,205)
 
(366)
 
(638)
 
(201)
 
-
 
 
-
 
 
-
 
Adjusting items
 
59
 
 
4
 
 
65
 
 
(11)
 
-
 
 
-
 
 
-
 
Impairment
 
85
 
 
4
 
 
65
 
 
15
 
 
-
 
 
-
 
 
-
 
Reversal of impairment
 
(26)
 
-
 
 
-
 
 
(26)
 
-
 
 
-
 
 
-
 
Adjusted exploration expenses
 
(1,146)
 
(361)
 
(573)
 
(212)
 
-
 
 
-
 
 
-
 
Net operating income/(loss)
 
78,811
 
 
67,614
 
 
3,248
 
 
4,022
 
 
3,612
 
 
(84)
 
399
 
Sum of adjusting items
 
(3,871)
 
(1,355)
 
559
 
 
(1,065)
 
(1,360)
 
(100)
 
(550)
Adjusted earnings/(loss)
 
74,940
 
 
66,260
 
 
3,806
 
 
2,957
 
 
2,253
 
 
(184)
 
(151)
Tax on adjusted earnings
 
(52,250)
 
(51,373)
 
(1,248)
 
(79)
 
474
 
 
14
 
 
(38)
Adjusted earnings/(loss) after tax
 
22,691
 
 
14,887
 
 
2,558
 
 
2,878
 
 
2,727
 
 
(170)
 
(189)
1) The adjustment in E&P International and
 
Other is related to recirculation of currency effects resulting
 
from exit of equity accounted companies.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor, Annual Report on Form 20-F 2022
 
325
Items impacting net operating income/(loss) in
the full year of 2021
Equinor
group
E&P
Norway
E&P
Internation
al
E&P USA
MMP
REN
Other
(in USD million)
Total revenues and other income
1)
 
90,924
 
 
39,386
 
 
5,566
 
 
4,149
 
 
87,393
 
 
1,411
 
(46,980)
Adjusting Items
 
(1,836)
 
(339)
 
43
 
 
-
 
 
(155)
 
(1,381)
 
(4)
Changes in fair value of derivatives
 
(146)
 
(145)
 
36
 
 
-
 
 
(37)
 
-
 
 
-
 
Periodisation of inventory hedging effect
 
49
 
 
-
 
 
-
 
 
-
 
 
49
 
 
-
 
 
-
 
Impairment from associated companies
 
4
 
 
-
 
 
-
 
 
-
 
 
-
 
 
4
 
 
-
 
Over-/underlift
 
(125)
 
(194)
 
69
 
 
-
 
 
-
 
 
-
 
 
-
 
Gain/loss on sale of assets
 
(1,561)
 
-
 
 
(5)
 
-
 
 
(167)
 
(1,385)
 
(4)
Provisions
 
(57)
 
-
 
 
(57)
 
-
 
 
-
 
 
-
 
 
-
 
Adjusted total revenues and other income
1)
 
89,088
 
 
39,047
 
 
5,609
 
 
4,149
 
 
87,238
 
 
30
 
(46,984)
Purchases [net of inventory variation]
 
(35,160)
 
(0)
 
(58)
 
(0)
 
(80,873)
 
(0)
 
45,771
 
Adjusting Items
 
230
 
 
-
 
 
-
 
 
-
 
 
(231)
 
-
 
 
461
 
Operational storage effects
 
(231)
 
-
 
 
-
 
 
-
 
 
(231)
 
-
 
 
-
 
Eliminations
 
461
 
 
-
 
 
-
 
 
-
 
 
-
 
 
-
 
 
461
 
Adjusted purchases [net of inventory variation]
 
(34,930)
 
(0)
 
(58)
 
(0)
 
(81,104)
 
(0)
 
46,232
 
Operating and administrative expenses
1)
 
(9,378)
 
(3,652)
 
(1,406)
 
(1,074)
 
(3,753)
 
(163)
 
670
 
Adjusting Items
 
(11)
 
62
 
 
(32)
 
35
 
 
(87)
 
-
 
 
12
 
Over-/underlift
 
23
 
 
55
 
 
(32)
 
-
 
 
-
 
 
-
 
 
-
 
Other adjustments
2)
 
(43)
 
7
 
 
-
 
 
-
 
 
(50)
 
-
 
 
-
 
Gain/loss on sale of assets
 
47
 
 
-
 
 
-
 
 
35
 
 
-
 
 
-
 
 
12
 
Provisions
 
(37)
 
-
 
 
-
 
 
-
 
 
(37)
 
-
 
 
-
 
Adjusted operating and administrative expenses
1)
 
(9,389)
 
(3,590)
 
(1,438)
 
(1,039)
 
(3,841)
 
(163)
 
682
 
Depreciation, amortisation and net impairments
1)
 
(11,719)
 
(4,900)
 
(3,321)
 
(1,734)
 
(1,604)
 
(3)
 
(156)
Adjusting Items
 
1,288
 
 
(1,102)
 
1,587
 
 
69
 
 
735
 
 
-
 
 
-
 
Impairment
 
2,963
 
 
276
 
 
1,836
 
 
116
 
 
735
 
 
-
 
 
-
 
Reversal of impairment
 
(1,675)
 
(1,379)
 
(250)
 
(47)
 
-
 
 
-
 
 
-
 
Adjusted depreciation, amortisation and net
impairments
1)
 
(10,431)
 
(6,002)
 
(1,734)
 
(1,665)
 
(869)
 
(3)
 
(156)
Exploration expenses
 
(1,004)
 
(363)
 
(451)
 
(190)
 
-
 
 
-
 
 
0
 
Adjusting Items
 
152
 
 
7
 
 
101
 
 
44
 
 
-
 
 
-
 
 
-
 
Impairment
 
175
 
 
7
 
 
101
 
 
66
 
 
-
 
 
-
 
 
-
 
Reversal of impairment
 
(22)
 
-
 
 
-
 
 
(22)
 
-
 
 
-
 
 
-
 
Adjusted exploration expenses
 
(852)
 
(356)
 
(350)
 
(146)
 
-
 
 
-
 
 
0
 
Net operating income/(loss)
1)
 
33,663
 
 
30,471
 
 
329
 
 
1,150
 
 
1,163
 
 
1,245
 
 
(695)
Sum of adjusting items
 
(177)
 
(1,372)
 
1,698
 
 
147
 
 
262
 
 
(1,381)
 
469
 
Adjusted earnings/(loss)
1)
 
33,486
 
 
29,099
 
 
2,028
 
 
1,297
 
 
1,424
 
 
(136)
 
(227)
Tax on adjusted earnings
 
(23,445)
 
(21,825)
 
(670)
 
(16)
 
(998)
 
23
 
 
40
 
Adjusted earnings/(loss) after tax
1)
 
10,042
 
 
7,274
 
 
1,358
 
 
1,281
 
 
426
 
 
(112)
 
(187)
1) E&P Norway, E&P International, MMP and Other segments are restated due
 
to implementation of IFRS 16 in the segments
2) The adjustment for MMP is related to an
 
insurance settlement.
326
 
Equinor, Annual Report on Form 20-F 2022
 
f) Total
 
shareholder return (TSR)
Total shareholder return (TSR) is the sum of a share’s price growth and dividends for the same period, divided by the share price at
beginning of period.
g) Gross capital expenditure (gross capex)
Capital expenditures, defined as Additions to PP&E, intangibles and equity accounted investments,
 
amounted to USD 10.0 billion in
2022 and USD 8.5 billion in 2021 (as referenced in note 5 Segments to the Consolidated
 
financial statements).
Gross capital expenditures are capital expenditures that are adjusted to exclude additions of Right
 
of use assets related to leases (as
referenced in note 12, Property, plant and equipment, to the consolidated financial statements) and to include Equinor’s proportionate
share of capital expenditures in equity accounted investments not included in additions to equity
 
accounted investments, within the
REN segment for 2021 and 2022. The calculation of gross capital expenditures excludes additions
 
to right of use assets related to
leases, as management believes that this better reflects the Group's investments in the
 
business to drive growth.
In 2022, a net total adjustment of USD 0.4 billion was excluded, resulting in gross capital
 
expenditures of USD 9.6 billion. In 2021, a
net total adjustment of USD 0.3 billion was included, resulting in gross capital expenditures of USD
 
8.8 billion.
Forward-looking gross capital expenditures included in this report are not reconcilable to its most
 
directly comparable IFRS measure
without unreasonable efforts, because the amounts excluded from such IFRS measure to determine gross capital
 
expenditures
cannot be predicted with reasonable certainty.
Equinor, Annual Report on Form 20-F 2022
 
327
5.9 Terms
 
and abbreviations
Organisational and other abbreviations
 
●
 
ACER
 
- European union agency for the cooperation of
 
energy reulators
●
 
ADS – American Depositary Share
●
 
ADR – American Depositary Receipt
●
 
ACG - Azeri-Chirag-Gunashli
●
 
AFP - Agreement-based early retirement plan
●
 
AGM - Annual general meeting
●
 
APS - Announced Pledges Scenario
●
 
ARO - Asset retirement obligation
●
 
BTC - Baku-Tbilisi-Ceyhan pipeline
●
 
CAPEX – capital expenditure
●
 
CEO
 
- Chief executive officer
●
 
CCS - Carbon capture and storage
●
 
CLOV - Cravo, Lirio, Orquidea and Violeta
●
 
CMU – Capital Markets Update
●
 
CO
2
 
- Carbon dioxide
●
 
CO
2
e - Carbon dioxide equivalent
●
 
CPL - Crude, Products and Liquids
●
 
DKK - Danish Krone
●
 
DISC - Data improvements, Shipping and Commercial operations
●
 
D&W - Drilling and Well
●
 
EEA - European Economic Area
●
 
EEX - European Energy Exchange
●
 
EFTA - European Free Trade Association
●
 
EMTN - Euro medium-term note
●
 
EPI - Exploration & Production International
●
 
EPN - Exploration & Production Norway
●
 
EPUSA - Exploration & Production USA
●
 
ESMA
 
- European securities and markets authority
●
 
EU - European Union
●
 
EU ETS - EU Emissions Trading System
●
 
EUR - Euro
●
 
EXP - Exploration
●
 
FPSO - Floating production, storage and offload vessel
●
 
FSO – Floating storage and offload vessel
●
 
GAAP - Generally accepted accounting principles
●
 
GBP - British Pound
●
 
GDP - Gross domestic product
●
 
GHG - Greenhouse gas
●
 
GSB - Global Strategy & Business Development
●
 
G&P - Gas and power
●
 
HSE - Health, safety and environment
●
 
IEA - International Energy Agency
●
 
IASB - International Accounting Standards Board
●
 
ICE - Intercontinental Exchange
●
 
IFRS - International Financial Reporting Standards
●
 
IMF – International Monetary Fund
●
 
IOGP - The International Association of Oil & Gas Producers
●
 
IOR - Improved oil recovery
●
 
LCS
 
- Low carbon solutions
●
 
LCOE - Levelised Cost of Energy
●
 
LNG - Liquefied natural gas
●
 
LPG - Liquefied petroleum gas
●
 
MMP - Marketing, Midstream & Processing
●
 
MPE - Norwegian Ministry of Petroleum and Energy
●
 
NCS - Norwegian continental shelf
●
 
NES – New Energy Solutions
●
 
NGL – Natural gas liquids
●
 
NIOC - National Iranian Oil Company
●
 
NOK - Norwegian kroner
●
 
NOx- Nitrogen oxide
●
 
NVC - New value chains
●
 
NYSE – New York stock exchange
328
 
Equinor, Annual Report on Form 20-F 2022
 
●
 
NYMEX - New York Mercantile Exchange
●
 
NZE - Net zero emissions
●
 
OECD - Organisation of Economic Co-Operation and
 
Development
●
 
OCI - Other Comprehensive Income
●
 
OML - Oil mining lease
●
 
OPEC - Organization of the Petroleum Exporting
 
Countries
●
 
OPEX – Operating expense
●
 
OPL - Operation plants
●
 
OSE – Oslo stock exchange
●
 
OTC - Over-the-counter
●
 
OTS - Oil trading and supply department
●
 
PDO - Plan for development and operation
●
 
PDP - Projects, Drilling and Procurement
●
 
PIO - Plan for installation and operation
●
 
PP&E - Property, plant and equipement
●
 
PS
A
- Production sharing agreement
●
 
PSC – Production sharing contract
●
 
PSVM - Plutão, Saturno, Vênus and Marte
●
 
R&D - Research and development
●
 
REN - Renewables
●
 
ROACE - Return on average capital employed
●
 
RRR - Reserve replacement ratio
●
 
SDFI - Norwegian State's Direct Financial Interest
●
 
SEC - Securities and Exchange Commission
●
 
SEK - Swedish Krona
●
 
SG&A - Selling, general & administrative
●
 
SIF - Serious Incident Frequency
●
 
TDI - Technology,
 
Digital & Innovation
●
 
TRIF - Total recordable injuries per million hours worked
●
 
TSP - Technical service provider
●
 
TSR - Total shareholder return
●
 
UKCS - UK continental shelf
●
 
UPC - Unit production cost
●
 
US - United States of America
●
 
USD - United States dollar
●
 
WACC - Weighted average cost of capital
●
 
YPF - Yacimientos Petrolíferos Fiscales S.A
Metric abbreviations etc.
●
 
bbl - barrel
●
 
mbbl - thousand barrels
●
 
mmbbl - million barrels
●
 
boe - barrels of oil equivalent
●
 
mboe - thousand barrels of oil equivalent
●
 
mmboe - million barrels of oil equivalent
●
 
mmmcf - billion cubic feet
●
 
MMBtu - million british thermal units
●
 
mcm - thousand cubic metres
●
 
mmcm - million cubic metres
●
 
bcm - billion cubic metres
●
 
km - kilometre
●
 
one billion - one thousand million
●
 
MJ - megajoule
●
 
MW - megawatt
●
 
MWh – megawatt hours
●
 
GW – gigawatt
●
 
GWh – gigawatt hours
●
 
TW – terawatt
●
 
TWh – terrawatt hours
●
 
SPR – strategic petroleum reserves
Equivalent measurements are based upon
●
 
1 barrel equals 0.134 tonnes of oil (33 degrees
 
API)
●
 
1 barrel equals 42 US gallons
●
 
1 barrel equals 0.159 standard cubic metres
●
 
1 barrel of oil equivalent equals 1 barrel
 
of crude oil
Equinor, Annual Report on Form 20-F 2022
 
329
●
 
1 barrel of oil equivalent equals 159 standard
 
cubic metres of natural gas
●
 
1 barrel of oil equivalent equals 5,612 cubic
 
feet of natural gas
●
 
1 barrel of oil equivalent equals 0.0837 tonnes
 
of NGLs
●
 
1 billion standard cubic metres of natural gas equals
 
1 million standard cubic metres of oil equivalent
●
 
1 cubic metre equals 35.3 cubic feet
●
 
1 kilometre equals 0.62 miles
●
 
1 square kilometre equals 0.39 square miles
●
 
1 square kilometre equals 247.105 acres
●
 
1 cubic metre of natural gas equals 1 standard
 
cubic metre of natural gas
●
 
1,000 standard cubic meter gas equals 1 standard
 
cubic meter oil equivalent
●
 
1,000 standard cubic metres of natural gas equals
 
6.29 boe
●
 
1 standard cubic foot equals 0.0283 standard
 
cubic metres
●
 
1 standard cubic foot equals 1000 British thermal units
 
(btu)
●
 
1 tonne of NGLs equals 1.9 standard
 
cubic metres of oil equivalent
●
 
1 degree Celsius equals minus 32 plus five-ninths of
 
the number of degrees Fahrenheit
Miscellaneous terms
●
 
Appraisal well: A well drilled to establish the extent
 
and the size of a discovery
●
 
Biofuel: A solid, liquid or gaseous fuel derived from relatively
 
recently dead biological material and is distinguished
 
from fossil fuels, which
are derived from long dead biological
 
material
●
 
BOE (barrels of oil equivalent): A measure
 
to quantify crude oil, natural gas liquids and natural
 
gas amounts using the same basis.
Natural gas volumes are converted to barrels on
 
the basis of energy content
●
 
Condensates: The heavier natural gas components,
 
such as pentane, hexane, iceptane and so
 
forth, which are liquid under atmospheric
pressure – also called natural gasoline or naphtha
●
 
Crude oil, or oil: Includes condensate and natural
 
gas liquids
●
 
Development: The drilling, construction, and related activities
 
following discovery that are necessary to
 
begin production of crude oil and
natural gas fields
●
 
Downstream: The selling and distribution of products derived
 
from upstream activities
●
 
Equity and entitlement volumes of oil and gas:
 
Equity volumes represent volumes produced under
 
a production sharing agreement (PSA)
that correspond to Equinor's percentage ownership in
 
a particular field. Entitlement volumes, on the
 
other hand, represent Equinor's
share of the volumes distributed to the partners in
 
the field, which are subject to deductions
 
for, among other things, royalties and the
host government's share of profit oil. Under
 
the terms of a PSA, the amount of profit oil deducted
 
from equity volumes will normally
increase with the cumulative return on investment
 
to the partners and/or production from the
 
licence. The distinction between equity and
entitlement is relevant to most PSA regimes, whereas
 
it is not applicable in most concessionary regimes
 
such as those in Norway, the
UK, Canada and Brazil. The overview of equity
 
production provides additional information for readers,
 
as certain costs described in the
profit and loss analysis were directly associated with
 
equity volumes produced during the reported
 
years
●
 
Heavy oil: Crude oil with high viscosity (typically
 
above 10 cp), and high specific gravity. The API classifies heavy oil as
 
crudes with a
gravity below 22.3° API. In addition to high viscosity
 
and high specific gravity, heavy oils typically have low hydrogen-to-carbon
 
ratios,
high asphaltene, sulphur, nitrogen, and heavy-metal content, as well
 
as higher acid numbers
●
 
High grade: Relates to selectively harvesting goods,
 
to cut the best and leave the rest. In reference
 
to exploration and production this
entails strict prioritisation and sequencing of drilling
 
targets
●
 
Hydro: A reference to the oil and energy
 
activities of Norsk Hydro ASA, which merged with
 
Equinor ASA
●
 
IOR (improved oil recovery): Actual measures resulting
 
in an increased oil recovery factor from
 
a reservoir as compared with the
expected value at a certain reference point in time. IOR
 
comprises both of conventional and emerging
 
technologies
●
 
Liquids: Refers to oil, condensates and NGL
●
 
LNG (liquefied natural gas): Lean gas - primarily methane
 
- converted to liquid form through refrigeration
 
to minus 163 degrees Celsius
under atmospheric pressures
●
 
LPG (liquefied petroleum gas): Consists primarily
 
of propane and butane, which turn liquid under
 
a pressure of six to seven atmospheres.
LPG is shipped in special vessels
●
 
Midstream: Processing, storage, and transport of crude
 
oil, natural gas, natural gas liquids and
 
sulphur
●
 
Naphtha: inflammable oil obtained by the dry distillation
 
of petroleum
●
 
Natural gas: Petroleum that consists principally of
 
light hydrocarbons. It can be divided into 1)
 
lean gas, primarily methane but often
containing some ethane and smaller quantities of
 
heavier hydrocarbons (also called sales gas) and 2)
 
wet gas, primarily ethane, propane
and butane as well as smaller amounts of
 
heavier hydrocarbons; partially liquid under
 
atmospheric pressure
●
 
NGL (natural gas liquids): Light hydrocarbons mainly
 
consisting of ethane, propane and butane which
 
are liquid under pressure at normal
temperature
●
 
Oil sands: A naturally occurring mixture of bitumen,
 
water, sand, and clay. A heavy viscous form of crude oil
●
 
Oil and gas value chains: Describes the value that
 
is being added at each step from 1) exploring;
 
2) developing; 3) producing; 4)
transportation and refining; and 5) marketing and
 
distribution
●
 
Oslo Børs: Oslo stock exchange (OSE)
●
 
Peer group: Equinor’s peer group consists
 
of Equinor, bp, Chevron, ConocoPhilips, Eni, ExxonMobil, Galp, Lundin,
 
Repsol, Shell,
TotalEnergies and Ørsted.
●
 
Petroleum: A collective term for hydrocarbons, whether
 
solid, liquid or gaseous. Hydrocarbons are compounds
 
formed from the elements
hydrogen (H) and carbon (C). The proportion
 
of different compounds, from methane and ethane up
 
to the heaviest components, in a
petroleum find varies from discovery to discovery. If a reservoir primarily contains
 
light hydrocarbons, it is described as a gas field.
 
If
330
 
Equinor, Annual Report on Form 20-F 2022
 
heavier hydrocarbons predominate, it is described
 
as an oil field. An oil field may feature free
 
gas above the oil and contain a quantity of
light hydrocarbons, also called associated gas
●
 
Proved reserves: Reserves claimed to have a
 
reasonable certainty (normally at least 90% confidence)
 
of being recoverable under
existing economic and political conditions and using
 
existing technology. They are the only type the US Securities and Exchange
Commission allows oil companies to report
●
 
Refining reference margin: Is a typical average
 
gross margin of our two refineries, Mongstad
 
and Kalundborg. The reference margin will
differ from the actual margin, due to variations in type
 
of crude and other feedstock, throughput, product
 
yields, freight cost, inventory etc
●
 
Rig year: A measure of the number of equivalent
 
rigs operating during a given period. It is
 
calculated as the number of days rigs are
operating divided by the number of days in
 
the period
●
 
Scope 1 GHG emissions: Direct GHG emissions
 
from operations that are owned and/or controlled
 
by the organisation (Source:
Greenhouse gas protocol). The global warming
 
potential (GWP) of CH4 is, in accordance with
 
the Intergovernmental Panel on Climate
Change (IPCC) Fifth Assessment Report (AR5) (2022),
 
considered to be 28 times the GWP of CO
₂
.
●
 
Upstream: Includes the searching for potential underground
 
or underwater oil and gas fields, drilling of
 
exploratory wells, subsequent
operating wells which bring the liquids and or
 
natural gas to the surface
●
 
VOC (volatile organic compounds): Organic chemical
 
compounds that have high enough vapour pressures
 
under normal conditions to
significantly vaporise and enter the earth's atmosphere (e.g.
 
gasses formed under loading and offloading of crude
 
oil)
Equinor, Annual Report on Form 20-F 2022
 
331
Sustainability terms and abbreviations
Announced Pledges (APS)
IEA scenario which includes all recent major national
 
announcements of 2030 targets and longer term
net zero and other pledges,
regardless of whether these have been anchored
 
in implementing legislation or in updated NDCs.
Area of high biodiversity value
Comprises “Key biodiversity areas” included in the
 
World Database on Key Biodiversity Areas managed
by International Union for Conservation of Nature (IUCN)
 
and Particularly Valuable and Sensitive Areas
(“Særlig verdifulle og sårbare områder”) on the Norwegian
 
Continental Shelf.
BECCS
Bioenergy with carbon capture and storage
BoD
Board of Directors.
BoD SSEC
BAC
BCC
Board of Directors’ Safety, Sustainability and Ethics Committee.
Board of Directors’ Audit Committee
Board of Directors’ Compensation and Executive
 
Development Committee
boe
Barrel of oil equivalent.
Capex
Capital expenditure.
CCS
Carbon capture and storage.
CCUS
Carbon capture, utilisation and storage.
CCSA
The CCSA is the trade association promoting the
 
commercial deployment of Carbon Capture, Utilisation
and Storage (CCUS).
Carbon dioxide (CO
₂
) emissions
CO
₂
 
released to the atmosphere as a result of our
 
processes and activities, including CO
₂
 
emissions
from energy generation, heat production, flaring (including
 
well testing/well work-over), and remaining
emissions from carbon capture and treatment plants.
 
Separate data compiled for Equinor operated
activities and equity basis.
Carbon dioxide (CO
₂
) emission
reductions
The total estimated quantity of CO
₂
 
emissions achieved by implementing a specific measure
 
compared
to the expected emissions at an installation without
 
the measure (or best available technology for
greenfield developments).
Carbon dioxide (CO
₂
) equivalents
Carbon dioxide equivalent is a quantity that describes,
 
for a given mixture and amount of greenhouse
gas, the amount of CO
₂
 
that would have the same global warming potential.
CDP
CDP is a not-for-profit charity that runs a global
 
disclosure system for investors, companies, cities,
 
states
and regions to report and benchmark their environmental
 
impacts.
CEC
Corporate Executive Committee
COSO
CSRD
The Committee of Sponsoring Organizations of
 
the Treadway Commission (COSO) is a joint initiative of
five professional organizations. Advises on developing
 
thought leadership that enhances internal
 
control,
risk management, governance and fraud deterrence.
EU Corporate Sustainability Reporting Directive
Dividends declared
D&I
 
Includes cash dividend and scrip dividend.
Diversity and inclusion
Economic value generated
Total revenues including income from sales of liquids on behalf of the Norwegian state’s direct financial
interest
EIA
Environmental Impact Assessment.
EITI
Extractives Industries Transparency Initiative.
Employee wages and benefits
Salaries, pensions, payroll tax and other compensations.
Energy consumption
Energy used for power generation and heat production
 
in combustion processes, unused energy
 
from
flaring (including well testing/work-over and
 
venting), energy sold/delivered to third parties and
 
gross
energy (heat and electricity) purchased.
EPA
ERM
Equinor’s Economic Planning Assumptions
Enterprise risk management
ESG
Referring to non-financial reporting topics “Environmental”,
 
“Social” and “Governance”.
FEED
Front End Engineering Design. Means Basic Engineering
 
conducted after completion of Conceptual
Design or Feasibility Study.
Flared hydrocarbons
Weight of hydrocarbons combusted in operational flare systems.
 
Includes safety and production flaring.
332
 
Equinor, Annual Report on Form 20-F 2022
 
For Equinor operated activities.
Flaring intensity
Volume of flared hydrocarbons from upstream activities (including LNG)
 
per thousand tonnes of
hydrocarbons produced.
Freshwater
GPS
Naturally occurring water with a low concentration
 
of salts, or generally accepted as suitable for
abstraction and treatment to produce potable water. Includes water from
 
public installations, wells
(including groundwater reservoirs), lakes, streams, rivers
 
and purchased freshwater. Freshwater
produced from salt water on facilities/installations is not
 
included.
Global people survey
GRI
Global Reporting Initiative is an independent, international
 
organisation that provide the world’s most
widely used standards for sustainability reporting – the
 
GRI Standards.
H
₂
S
Hydrogen sulfide is a highly toxic and flammable
 
gas.
Hazardous waste
Waste is considered to be hazardous waste according to
 
the regulations under which the activity
operates or where the waste can pose a substantial
 
hazard to human health and/or the environment
when improperly managed.
HOP
Human and organisational performance.
Human rights steering committee
(HRSC)
Equinor steering committee mandated by the Corporate
 
Executive Committee (CEC) to oversee and
provide guidance to the implementation of Equinor’s
 
human rights policy.
IDD
Integrity Due Diligence (IDD) is performed to identify
 
known integrity concerns, prior to establishing a
new agreement with a counterparty.
IEA
IETA
IFC
ILO
International Energy Agency.
International Emissions Trading Association
International Finance Corporation
International Labour Organization
IOGP
The International association of Oil & Gas Producers.
IPCC
IUCN
Intergovernmental Panel on Climate Change.
International Union for Conservation of Nature
KPI
Key Performance Indicator.
LNG
Liquefied natural gas.
LPG
Liquefied petroleum gas.
Low carbon research and
development (R&D) expenditure
The share of annual research expenditures, in percentages
 
of total R&D expenditures, spent on new
energy solutions and energy efficiency technologies.
Methane emissions
CH_{4} released to the atmosphere including emissions
 
from energy generation and heat production
 
at
own plants, flaring (including well testing/well work-over),
 
cold venting, diffuse emissions, and the
storage and loading of crude oil.
Methane intensity
Total methane emissions from our up- and midstream oil and gas activities divided by the
 
marketed gas,
both on a 100 % operated basis.
MoU
Memorandum of Understanding. A memorandum of
 
understanding is an agreement between two or
more parties outlined in a formal document.
 
It is not legally binding but signals the willingness
 
of the
parties to move forward with a contract. The MOU
 
can be seen as the starting point for negotiations
 
as it
defines the scope and purpose of the talks.
MSc
Master of Science degree.
NCS
The Norwegian Continental Shelf
Net carbon intensity (NCI)
GHG emissions associated with the production
 
and use of energy produced by Equinor, including
negative emissions related to carbon services and
 
offsets, divided by the amount of energy produced
 
by
the company (gCO
₂
e/MJ). A detailed description of the net carbon
 
intensity indicator is available at
equinor.com.
Net income
Net profit after all revenues, income items and
 
expenses have been accounted for.
Equinor, Annual Report on Form 20-F 2022
 
333
Net zero emissions ambition
Covers scope 1 and 2 GHG emissions on an
 
operational control basis (100%) and scope 3 GHG
emissions (use of products, category 11, on an equity share basis).
NGO
Non-governmental organisation. A non-profit organization
 
that operates independently of any
government, typically one whose purpose is to
 
address a social or political issue.
Nitrogen oxides (NO
X
)
Nitrogen oxides, as nitrous compounds in fuel released
 
from power generation and heat production,
flaring and process.
Non-hazardous waste
Waste that is not defined as hazardous waste. This excludes
 
drill cuttings and produced and flow-back
water from our USA onshore operations which
 
are exempted from regulation and are registered
separately as ‘exempted waste’.
Non-methane volatile organic
compounds (nmVOC) emissions
nmVOC released to the atmosphere from power generation
 
and heat production, flaring (including well
testing/well work-over), process, cold venting and
 
fugitives.
NPV
Net Present Value.
n/r
Not reported.
OGCI
Oil and Gas Climate Initiative.
Oil spill
All unintentional release of a liquid petroleum hydrocarbon
 
into the natural environment.
Operations
Temporary or permanent sites, activities and assets used for exploration, extraction, refining,
transporting, distributing, and marketing petroleum
 
products.
Payments to governments
Payments made directly by Equinor to governments,
 
such as income tax, host government entitlements
(value), bonuses, royalties and fees, related to exploration
 
and production activities. Includes
environmental fees and taxes. Payments made on behalf
 
of other license partners, e.g. area fees,
 
are
included.
Produced water
Water that is brought to the surface during operations which
 
extract hydrocarbons from oil and gas
reservoirs.
Protected area
A protected area is a clearly defined geographical
 
space, recognised, dedicated and managed, through
legal or other effective means, to achieve the long-term
 
conservation of nature with associated
ecosystem services and cultural values. (IUCN Definition
 
2008)
Purchase of goods and services
Part of the cost is charged to partners in activities
 
we operate.
Recovered waste
Waste from Equinor operated activities that has been delivered
 
for reuse, recycling or incineration with
energy recovery.
Regular discharges of oil in
water to sea
Oil in regulated or controlled discharges to the
 
sea from Equinor operated activities. This includes
produced water, process water, displacement water, ballast water, jetting water, drainage water and
water discharged from treatment plants.
RES
RES is the world’s largest independent renewable energy
 
company.
Scope 1 GHG emissions
Direct GHG emissions from operations that are owned
 
and/or controlled by the organisation (Source:
Greenhouse gas protocol). The global warming
 
potential (GWP) of CH4 is, in accordance with
 
the
Intergovernmental Panel on Climate Change (IPCC)
 
Fourth Assessment Report (AR4) (2007),
considered to be 25 times the GWP of CO
₂
.
Scope 2 GHG emissions
Indirect GHG emissions from energy imported
 
from third parties, heating, cooling, and steam consumed
within the organisation. We use IEA/NVE/e-grid (location-based)
 
and AIB (market-based) as sources of
scope 2 emissions factor, expressed as kg CO
₂
/kWh. The location-based calculation method reflects
 
the
emissions intensity of grids, taking electricity trade adjustments
 
into account. The market-based
calculation method reflects emissions from electricity that
 
companies have purposefully chosen (or their
lack of choice). It derives emission factors from
 
contracts between two parties for the sale and
 
purchase
of energy bundled with attributes about the
 
energy generation, or for unbundled attribute claims.
 
(Source:
Greenhouse gas protocol). When no such contracts are
 
in place, residual mix emission factors are
 
used.
Scope 3 GHG emissions
All GHG emissions that occur as a consequence
 
of the operations of the organisation but are
 
not directly
controlled or owned by the company, such as use of sold products (equity
 
basis). Emissions from use of
sold products is calculated from IPCC emission
 
factors, combined with IEA statistics on regional
 
energy
consumption.
SDG
The United Nations’ Sustainable Development Goals.
SDS
The International Energy Agency’s (IEA) Sustainable Development
 
Scenario.
Serious incident frequency (SIF)
The number of serious incidents (including near
 
misses) per million hours worked. An incident
 
is an
event or chain of events that has caused or
 
could have caused injury, illness and/or damage to/loss of
property, the environment or a third party. All undesirable incidents are categorised according to degree
of seriousness, based on established categorisation
 
matrices.
SHE Index
Index to reflect the status of diversity and inclusion
 
in corporate life, created by EY.
334
 
Equinor, Annual Report on Form 20-F 2022
 
Shift
Center of expertise on the UN Guiding Principles
 
on Business and Human Rights
Sickness absence
The total number of sickness absence hours
 
as a percentage of planned working hours
 
(Equinor ASA
employees).
Social investments,
sponsorships and donations
Includes voluntary and contractual payments. Part of the
 
cost is charged to partners in activities we
operate.
STEM
Science, technology, engineering and mathematics.
Stated Policies (STEPS)
IEA scenario STEPS provides a conservative benchmark
 
for the future, because it does not take it
 
for
granted that governments will reach all announced
 
goals. Includes what has actually been put in
 
place to
reach these and other energy-related objectives.
Sulphur oxides (SOX) emissions
SOX released from power generation and heat production
 
flaring and process.
TCFD
TNFD
Task Force on Climate-related Financial Disclosures.
Task Force on Nature-related Financial Disclosures
The Paris Agreement
A legally binding international treaty on climate change.
 
It was adopted by 196 Parties at COP 21
 
in
Paris, on 12 December 2015 and entered into
 
force on 4 November 2016. Its goal is to limit global
warming to well below 2, preferably to 1.5 degrees
 
Celsius, compared to pre-industrial levels.
Total recordable injury frequency
(TRIF)
Number of fatal accidents, lost-time injuries, injuries
 
involving substitute work and medical treatment
injuries at work, per million hours worked, amongst
 
Equinor employees and contractors.
Total Serious incident frequency
(SIF)
The number of actual and potential serious safety
 
incidents categorised with a level 1 or
 
2 out of five
degrees of seriousness per million hours worked.
UNGC
United Nations Global Compact. A voluntary initiative
 
to implement universal sustainability principles and
to take steps to support UN goals.
UNGP
United Nations Guiding Principles on Business and
 
Human Rights.
Upstream CO
₂
 
intensity
Total scope 1 emissions of CO
₂
 
(kg CO
₂
) from exploration and production, divided by
 
total production
(boe).
VPSHR:
Voluntary Principles on Security and Human Rights.
Water stress
The World Resources Institute’s Aqueduct® tool is used to determine
 
baseline water stress, which is the
ratio of total annual water withdrawal from a
 
catchment to average annual available water to the
 
same
catchment. The Aqueduct® tool classifies stress into
 
five levels, Low, Low-medium, Medium-high, High
and Extremely high. (Aqueduct® indicator: Baseline
 
Water Stress).
Waste
WBCSD
WEF
Materials are defined as waste when; they are
 
classified as such according to the regulations
 
under
which the activity operates or where the material
 
is contained and intended to be transported for further
handling and/or re-use or disposal by a 3rd party. Residual materials from
 
industrial activity, which are
discharged, recycled, injected or reused at the place
 
of generation as part of the consented operations,
are not included.
World Business Council for Sustainable Development
World Economic Forum
Work related illness (WRI)
Number of illnesses amongst Equinor employees and
 
contractors arising due to work activities.
Equinor, Annual Report on Form 20-F 2022
 
335
5.10 Forward-looking statements
This integrated annual report contains certain forward-looking statements that involve risks
 
and uncertainties, in particular in the
sections "Equinor’s market perspective" and "Equinor’s strategy".
 
In some cases, we use words such as "aim", "ambition", "anticipate",
"believe", "continue", "could", "estimate", "expect", "intend", "likely", "objective", "outlook", "may",
 
"plan", "schedule", "seek", "should",
"strategy", "target", "will", "goal" and similar expressions to identify forward-looking statements. All statements
 
other than statements
of historical fact, including: the commitment to develop as a broad energy company and ambition
 
to be a leading company in the
energy transition; ambition to reach net zero by 2050 and expectations regarding progress on our energy
 
transition plan and just
transition plan; our ambitions regarding reduction in operated emissions and net carbon intensity
 
and allocation of gross capex* to
renewables and low carbon solutions; our ambitions to decarbonise and maintain value in oil and gas,
 
industrialise and upscale
offshore wind, industrialise and commercialise carbon capture and storage and upscale and develop new value
 
chains in hydrogen;
ambition to attain a leadership position in the European CCS market; aims, expectations
 
and plans for renewables production capacity
and power generation, investments in renewables and low-carbon solutions and the balance between
 
oil and renewables production;
our expectations with respect to net carbon intensity, operated emissions, carbon and methane intensity and flaring reductions; our
internal carbon price and other financial metrics for investment decisions; break-even considerations
 
and targets; aims and
expectations regarding Equinor’s resilience across different climate scenarios; future levels of, and expected
 
value creation from, oil
and gas production, scale and composition of the oil and gas portfolio, and development
 
of CCS and hydrogen businesses; use of
compensation and offset mechanisms and high-quality carbon sinks; plans to develop fields; our intention to optimise and mature
 
our
portfolio; future worldwide economic trends, market outlook and future economic projections and
 
assumptions, including commodity
price assumptions; expectations and plans regarding capital expenditures; future financial performance, including
 
cash flow, liquidity
and return on average capital employed (ROACE)*; expectations regarding cash flow and returns from
 
our oil and gas portfolio and
renewable projects; organic capital expenditures through 2026; expectations and estimates regarding production and
 
execution of
projects; the ambition to keep unit of production cost in the top quartile of our peer group;
 
scheduled maintenance activity and the
effects thereof on equity production; business strategy and competitive position; sales, trading and market strategies;
 
research and
development initiatives and strategy, including ambitions regarding allocation of research and development capital towards
renewables and low carbon-solutions; expectations related to production levels, unit production cost, investment,
 
exploration activities,
discoveries and development in connection with our ongoing transactions and projects; our ambitions, expectations
 
and plans
regarding diversity and inclusion and employee training; plans and expectations regarding completion and results
 
of acquisitions,
disposals and other contractual arrangements and delivery commitments; plans, ambitions and expectations
 
regarding recovery
factors and levels, future margins and future levels or development of capacity, reserves or resources; planned turnarounds and other
maintenance activity; expectations regarding oil and gas volume growth, including for volumes lifted
 
and sold to equal entitlement
production; estimates related to production and development, forecasts, reporting levels and
 
dates; operational expectations,
estimates, schedules and costs; expectations relating to licences and leases; oil, gas,
 
alternative fuel and energy prices, volatility,
supply and demand; plans and expectations regarding processes related to human rights laws, corporate
 
structure and organizational
policies; technological innovation, implementation, position and expectations; expectations regarding
 
role and composition of the
board and our remuneration policies; our goal of safe and efficient operations; effectiveness of our internal policies and plans; our
ability to manage our risk exposure, our liquidity levels and management of liquidity reserves;
 
future credit ratings; estimated or future
liabilities, obligations or expenses; expected impact of currency and interest rate fluctuations; projected
 
outcome, impact or timing of
HSE regulations; HSE goals and objectives of management for future operations; our ambitions and
 
plans regarding biodiversity
(including our aim to develop a net-positive impact approach for projects) and value creation for
 
society; expectations related to
regulatory trends; impact of PSA effects; projected impact or timing of administrative or governmental rules,
 
standards, decisions,
standards or laws (including taxation laws); projected impact of legal claims against us; plans for
 
capital distribution, share buy-backs
and amounts and timing of dividends are forward-looking statements.
You should not place undue reliance on these forward-looking statements. Our actual results could differ materially from those
anticipated in the forward-looking statements for many reasons, including the risks described
 
above in "Risk factors", and elsewhere in
this integrated annual report.
 
These forward-looking statements reflect current views about future events, are based on management’s current expectations
 
and
assumptions and are, by their nature, subject to significant risks and uncertainties because they
 
relate to events and depend on
circumstances that will occur in the future. There are a number of factors that could cause
 
actual results and developments to differ
materially from those expressed or implied by these forward-looking statements, including levels
 
of industry product supply, demand
and pricing, in particular in light of significant oil price volatility and the uncertainty caused by the European
 
security situation, including
Russia’s invasion of Ukraine; unfavorable macroeconomic conditions and inflationary pressures; exchange rate and interest rate
fluctuations; levels and calculations of reserves and material differences from reserves estimates; regulatory stability
 
and access to
resources, including attractive low carbon opportunities; the effects of climate change and changes in stakeholder
 
sentiment and
regulatory requirements regarding climate change; changes in market demand and supply for renewables; inability
 
to meet strategic
objectives; the development and use of new technology; social and/or political instability, including as a result of Russia’s invasion of
Ukraine; failure to manage digital and cyber threats; operational problems; unsuccessful drilling;
 
availability of adequate infrastructure;
the actions of field partners and other third-parties; reputational damage; the actions of competitors;
 
the actions of the Norwegian
state as majority shareholder and exercise of ownership by the Norwegian state; changes or uncertainty
 
in or non-compliance with
laws and governmental regulations; adverse changes in tax regimes; the political and economic
 
policies of Norway and other oil-
336
 
Equinor, Annual Report on Form 20-F 2022
 
producing countries; regulations on hydraulic fracturing and low-carbon value chains; liquidity, interest rate, equity and credit risks;
risks relating to trading and commercial supply activities; an inability to attract and retain
 
personnel; ineffectiveness of crisis
management systems; inadequate insurance coverage; health, safety and environmental risks;
 
physical security risks; failure to meet
our ethical and social standards; non-compliance with international trade sanctions; and other factors
 
discussed elsewhere in this
integrated annual report.
 
The achievement of Equinor’s climate ambitions depends, in part, on broader societal shifts in
 
consumer demands and technological
advancements, each of which are beyond Equinor’s control. Should society’s demands and technological
 
innovation not shift in
parallel with Equinor’s pursuit of its energy transition plan, Equinor’s ability
 
to meet its climate ambitions will be impaired. The
calculation of Equinor’s net carbon intensity presented in this report includes
 
an estimate of emissions from the use of sold products
(GHG protocol category 11) as a means to more accurately evaluate the emission lifecycle of what we produce to respond to the
energy transition and potential business opportunities arising from shifting consumer demands.
 
Including these emissions in the
calculations should in no way be construed as an acceptance by Equinor of responsibility for the
 
emissions caused by such use.
The reference to any scenario in this report, including any potential net-zero scenarios, does not imply
 
Equinor views any particular
scenario as likely to occur. Third-party scenarios discussed in this report reflect the modeling assumptions and outputs of their
respective authors, not Equinor, and their use by Equinor is not an endorsement by Equinor of their underlying assumptions, likelihood
or probability. Investment decisions are made on the basis of Equinor’s separate planning process. Any use of the modeling of a third-
party organization within this report does not constitute or imply an endorsement by Equinor of any
 
or all of the positions or activities
of such organization.
We use certain terms in this document, such as “resource” and “resources” that the SEC’s rules prohibit us from including in
 
our filings
with the SEC. U.S. investors are urged to closely consider the disclosures in our annual report
 
on Form 20-F, SEC File No. 1-15200,
which is available on our website or by calling 1-800-SEC-0330 or logging on to www.sec.gov.
 
Although we believe that the expectations reflected in the forward-looking statements are reasonable, we
 
cannot assure you that our
future results, level of activity, performance or achievements will meet these expectations. Moreover, neither we nor any other person
assumes responsibility for the accuracy and completeness of the forward-looking statements. Unless
 
we are required by law to update
these statements, we will not necessarily update any of these statements after the
 
date of this integrated annual report, either to make
them conform to actual results or changes in our expectations.
Equinor 2022 Reserves Report
 
1
exhibit155p2i0
Equinor 2022 Reserves Report
 
2
2022 Oil and gas reserves report
Equinor 2022 Reserves Report
 
3
Introduction
 
About the report
This report presents Equinor`s proved oil and gas reserves
 
as of 31 December 2022. Proved oil and gas
 
reserves are those quantities of oil
and gas, which, by analysis of geoscience and engineering
 
data, can be estimated with reasonable certainty
 
to be economically producible—
from a given date forward, from known reservoirs,
 
and under existing economic conditions,
 
operating methods, and government regulations—
prior to the time at which contracts providing
 
the right to operate expire, unless evidence
 
indicates that renewal is reasonably certain,
regardless of whether deterministic or probabilistic
 
methods are used for the estimation. The
 
project to extract the hydrocarbons must have
commenced or the operator must be reasonably certain
 
that it will commence the project within a
 
reasonable time.
In alignment with industry practice and regulatory requirements,
 
we report operational performance and supplementary
 
oil and gas information
(unaudited). Numbers have been prepared in accordance
 
with the reserve definitions of Rules 4-10(a)
 
(1)-(32) of Regulations S-X of the
United States Securities and Exchange Commission (SEC).
 
All numbers are internal estimates produced
 
by Equinor. Estimates of reserves
should be regarded only as estimates that may
 
change over time as further production history
 
and additional information becomes available.
The determination of these reserves is part of
 
an ongoing process subject to continual revision.
 
Moreover, identified reserves and contingent
resources that may become proved in the future
 
are excluded from the estimates of proved reserves
 
provided in this report.
The Oil and gas reserves report may be downloaded
 
from Equinor`s website at www.equinor.com/reports.
 
The report is also included as
Exhibit 15.5 to the 2022 annual report on Form
 
20-
F.
exhibit155p4i0
Equinor 2022 Reserves Report
 
4
Operational performance
Proved oil and gas reserves
Proved oil and gas reserves were estimated to be 5,191 million boe at year end 2022, compared
 
to 5,356 million boe at the end of
2021.
Changes in proved reserves estimates are most commonly the result of revisions of estimates
 
due to observed production
performance or changes in prices or costs, extensions of proved areas through drilling activities or the inclusion
 
of proved reserves in
new discoveries through the sanctioning of new development projects. These changes are the result
 
of continuous business
processes and can be expected to continue to affect reserves in the future.
Proved reserves can also be added or subtracted through purchases and sales of reserves-in-place
 
or factors outside management
control.
Changes in oil and gas prices can affect the quantities of oil and gas that can be recovered from
 
the accumulations. Higher oil and
gas prices will normally allow more oil and gas to be recovered, while lower prices will normally result
 
in reduced recovery. However,
for fields with production sharing agreements (PSA), higher prices may result in reduced entitlement to
 
produced volumes and lower
prices may result in increased entitlement to produced volumes. These described changes are included in
 
the revisions and improved
recovery (IOR) category in the tables that follows in this report.
The principles for booking proved gas reserves are limited to contracted gas sales or gas with
 
access to a robust gas market.
Equinor prepares its disclosures for oil and gas reserves and certain other supplemental oil and gas disclosures
 
by geographical area,
as required by the US Securities and Exchange Commission (SEC). The geographical areas are
 
defined by country and continent.
These are Norway, Eurasia excluding Norway, Africa, the USA and the Americas excluding USA.
In Norway and other countries where there is a high degree of certainty that the authorities will
 
approve the plan for development and
operation (PDO), Equinor recognises reserves as proved undeveloped reserves when the PDO is submitted
 
to the authorities.
Otherwise, reserves are generally booked as proved undeveloped reserves when regulatory approval is
 
received, or when such
approval is imminent. Undrilled well locations in onshore fields in the USA are generally
 
booked as proved undeveloped reserves
when a development plan has been adopted and the well locations are scheduled to be drilled
 
within five years.
Approximately 87% of Equinor’s proved reserves are located in the Organisation
 
of Economic Co-Operation and Development
(OECD) countries. Norway is by far the most important contributor in this category, followed by the USA. Of Equinor's total proved
reserves, 5% are related to PSAs in non-OECD countries such as Angola, Brazil, Azerbaijan, Algeria,
 
Nigeria and Libya. Other proved
non-OECD reserves are related to concession fields in Argentina and Brazil, representing all together
 
7% of Equinor's total proved
reserves.
exhibit155p5i0
Equinor 2022 Reserves Report
 
5
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
exhibit155p6i0 exhibit155p6i1
Equinor 2022 Reserves Report
 
6
Changes in proved reserves in 2022
The total volume of proved reserves decreased by 165 million boe in 2022.
Change in proved reserves
For the year ended 31 December
(million boe)
2022
2021
2020
Revisions and improved recovery (IOR)
344
596
(171)
Extensions and discoveries
278
306
131
Purchases of reserves-in-place
36
-
6
Sales of reserves-in-place
(128)
(96)
-
Total reserve additions
530
806
(34)
Production
(695)
(710)
(710)
Net change in proved reserves
(165)
96
(744)
Revisions and IOR
Revisions of previously booked reserves, including the effect of improved recovery, increased the proved reserves by
 
net 344 million boe in 2022. The increase is the result of 433 million boe in
 
positive revisions and increased recovery, partially offset
by 89 million boe in negative revisions. Many producing fields had positive revisions due to
 
better performance, new drilling targets
and improved recovery measures, as well as reduced uncertainty due to further drilling and
 
production experience. The positive
revisions also included a direct effect of higher commodity prices, increasing the proved reserves by approximately
 
63 million boe
through increased economic lifetime on several fields. The negative revisions were mainly related to unforeseen
 
events and
operational challenges resulting in reduced production potential on some fields in addition to reduced
 
entitlement volumes from
several fields with PSAs.
Extensions and discoveries
A total of net 278 million boe of new proved reserves were added through extensions and
 
discoveries. Continuous extension of the
proved area in the Appalachian basin together with a record number of submitted PDOs in Norway, of which Munin and Halten Øst
were the largest, are the main contributors in this category.
In addition, this category includes extensions of proved areas through
drilling of new wells in previously undrilled areas at other fields in Norway and in Argentina.
Purchases and sales of reserves-in-place
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor 2022 Reserves Report
 
7
A total of 36 million boe of new proved reserves in the Statfjord Area, which covers the Norwegian
 
continental shelf (NCS) and UK
continental shelf, were purchased in 2022.
A
total of 128 million boe of sales of reserves-in-place are related to the exit of joint arrangements in Russia
 
in addition to the sale of
the Ekofisk Area and a minority share in the Martin Linge field on the NCS. Equinor
 
has no remaining proved reserves in Russia at
year end 2022.
In the fourth quarter of 2021, Equinor entered into an agreement to divest our interests
 
in the Corrib field in Ireland. Closing is
dependent on governmental approval and is expected to take place in the first quarter
 
of 2023. The sale will result in an estimated
reduction in proved reserves of approximately 11 million boe.
Production
The 2022 entitlement production was 695 million boe, down from 710 million boe in 2021 due to
 
sales, natural decline and operational
challenges.
Development of reserves
 
In 2022, 241 million boe were matured from proved undeveloped to proved developed reserves. Continued
 
drilling in the Appalachian
basin in the USA and on major offshore assets in addition to the production start of Askeladd (Snøhvit),
 
Johan Sverdrup Phase 2 and
Peregrino Phase 2 contributed to the major portion of maturation of proved undeveloped
 
to proved developed reserves in 2022.
Smaller volumes are related to individual assets world-wide. The positive revision
 
and improved recovery of proved developed
reserves of 322 million boe is related to increased economic lifetime at some fields, increased
 
activity levels, higher commodity prices
and implementation of improved recovery projects. Finally, 256 million boe was added to proved undeveloped reserves through
extensions and discoveries, the largest of these being Munin and Halten Øst in Norway, in addition to further development in the
Appalachian basin in the USA.
In 2021, 881 million boe were matured from proved undeveloped to proved developed reserves. Production
 
start of the Troll Phase 3
project and the Martin Linge field added more than 600 million boe to the proved
 
developed reserves. Continued drilling in the
Appalachian basin in the USA and in the Oseberg, Johan Sverdrup, and Snorre fields in Norway
 
increased the proved developed
reserves by 180 million boe during 2021. The
remaining 100 million boe of the matured volume is related to a wide range
 
of activities
on assets world-wide. The positive revisions of both proved developed reserves of
 
471 million boe and proved undeveloped reserves
of 125 million boe are related to higher commodity prices, increasing economic lifetime at some fields,
 
as well as increased activity
levels. Undeveloped extensions and discoveries of 269 million boe are dominated by the onshore assets
 
in the Appalachian basin and
in Argentina, together with the Bacalhau field in Brazil and the Johan Castberg field in
 
Norway.
In 2020, 250 million boe were matured from proved undeveloped to proved developed reserves. Continued
 
drilling in the Appalachian
basin in the USA and in the Johan Sverdrup, Ærfugl and Oseberg fields in Norway, increased the proved developed reserves by
 
200
million boe during 2020. The remaining 50 million boe of the matured volume was related to
 
a wide range of activities on assets world-
wide. The negative revision of proved undeveloped reserves of 131 million boe was both related
 
to lower commodity prices,
decreasing economic lifetime at some fields, as well as reduced activity levels and operational
 
challenges This resulted in a reduction
of proved undeveloped reserves, particularly in the onshore assets in the USA, in fields in Brazil
 
and in the UK.
Over the last five years, Equinor has matured 2,376 million boe of proved undeveloped reserves
 
to proved developed reserves.
Development of proved reserves
2022
2021
2020
(million boe)
Total
proved
reserves
Developed
Undeveloped
Total
proved
reserves
Developed
Undeveloped
Total
proved
reserves
Developed
Undeveloped
At 1 January
5,356
3,818
1,538
5,260
3,222
2,038
6,004
3,679
2,325
Revisions and improved
recovery
344
322
22
596
471
125
(171)
(40)
(131)
Extensions and discoveries
278
22
256
306
37
269
131
37
94
Purchases of reserves-in-place
36
29
7
-
-
-
6
6
0
Sales of reserves-in-place
(128)
(66)
(62)
(96)
(83)
(13)
-
-
-
Production
(695)
(695)
-
(710)
(710)
-
(710)
(710)
-
Moved from undeveloped to
developed
-
241
(241)
-
881
(881)
-
250
(250)
At 31 December
5,191
3,672
1,519
5,356
3,818
1,538
5,260
3,222
2,038
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor 2022 Reserves Report
 
8
Proved developed and undeveloped reserves
As of 31 December 2022
Oil and
condensate
NGL
Natural gas
Total oil and
gas
 
(mmboe)
(mmboe)
(mmmcf)
(mmboe)
Developed
Norway
731
149
10,294
2,714
Eurasia excluding Norway
35
3
89
53
Africa
107
8
91
131
USA
161
51
1,921
554
Americas excluding USA
216
-
25
220
Total developed proved reserves
1,249
210
12,420
3,672
Undeveloped
Norway
562
60
2,087
994
Eurasia excluding Norway
48
0
5
50
Africa
17
0
-
17
USA
56
9
423
140
Americas excluding USA
316
-
11
318
Total undeveloped proved reserves
999
70
2,526
1,519
Total proved reserves
2,248
280
14,946
5,191
As of 31 December 2022, the total proved undeveloped reserves amounted to 1,519 million boe,
 
65% of which are related to fields in
Norway. The Johan Sverdrup,
 
Snøhvit and Oseberg area fields, which have continuous development activities, together with
 
fields not
yet in production, such as Johan Castberg and Munin, have the largest proved undeveloped reserves
 
in Norway. The largest assets
with proved undeveloped reserves outside Norway, are Bacalhau,
 
Peregrino and Roncador in Brazil, the Appalachian basin, Vito and
Caesar-Tonga in the USA, Mariner in the UK, and ACG in Azerbaijan. All these fields are either producing or will start production
within the next five years.
For fields with proved reserves where production has not yet started, investment
 
decisions have already been sanctioned and
investments in infrastructure and facilities have commenced. There are no material development
 
projects, which would require a
separate future investment decision by management, included in our proved reserves. Some offshore development activities will
 
take
place more than five years from the disclosure date on many fields, but these are mainly
 
related to incremental type of spending, such
as drilling of additional wells from existing facilities, in order to secure continued production.
For projects under development, the Covid-19 pandemic impacted progress due to personnel limitations
 
on offshore as well as
onshore facilities and yards. The
 
pandemic has delayed production start at the Johan Castberg field in Norway. The field was
originally planned to start production in 2022, four years after the field development was
 
sanctioned. The
 
start-up is delayed to 2024.
For our onshore assets, all proved undeveloped reserves are limited to wells that are scheduled to be drilled
 
within five years.
In 2022, Equinor incurred USD 6.9 billion in development costs relating to assets carrying
 
proved reserves, of which USD 5.8 billion
was related to proved undeveloped reserves.
Reserves replacement
The reserves replacement ratio is defined as the net amount of proved reserves added divided by
 
produced volumes in any given
period.
The 2022 reserves replacement ratio was 76% and the corresponding
 
three-year average was 62%.
The organic reserves replacement ratio, excluding sales and purchases, was 89% in 2022 compared to 127% in
 
2021. The organic
average three-year replacement ratio was 70% at the end of 2022 compared to 68% at the end of 2021.
 
 
 
 
 
 
 
 
exhibit155p9i0
Equinor 2022 Reserves Report
 
9
Reserves replacement ratio
For the year ended 31 December
2022
2021
2020
Annual
76%
113%
(5%)
Three-year-average
62%
61%
95%
Proved reserves by region
Proved reserves in Norway
A total of 3,708 million boe was recognised as proved reserves on the NCS, representing
 
71% of Equinor's total proved reserves at
year end 2022. Of these, 3,208 million boe are related to fields and field areas
 
currently in production, 94% of which is operated by
Equinor.
Production experience, further drilling and improved recovery on many of Equinor’s
 
producing fields contributed with positive revisions
of 318 million boe in 2022. Negative revisions totalled 43 million boe and were mainly related
 
to operational challenges. Higher
commodity prices increased the proved reserves by 74 million boe. PDOs for several new fields have
 
been submitted to the
Norwegian Ministry of Petroleum and Energy in 2022, contributing to extensions and discoveries which
 
totalled 181 million boe in
2022. This increase also included the addition of new segments to some fields.
Of total proved reserves on the NCS, 2,714 million boe (73%) are proved developed reserves
 
at year end 2022. Of the total proved
reserves in this area, 60% are gas reserves mainly related to large fields such as Troll, the Oseberg area and
 
Snøhvit, and 40% are
liquid reserves mainly related to large fields such as Johan Sverdrup, Snorre and the Oseberg
 
area.
exhibit155p10i0 exhibit155p10i1
Equinor 2022 Reserves Report
 
10
Proved reserves in Eurasia, excluding Norway
A total of 103 million boe was recognised as proved reserves in the United Kingdom, Azerbaijan
 
and Ireland at year end 2022.
Eurasia excluding Norway represents 2% of Equinor's total proved reserves. All fields in this area
 
are producing. The sale of our
interest in joint arrangements in Russia in 2022 resulted in a reduction of proved reserves
 
of 86 million boe.
Of total proved reserves in Eurasia excluding Norway,
 
53 million boe (52%) are proved developed reserves at year end 2022. Of the
total proved reserves in this area, 84% are liquid reserves mainly related to larger fields such as
 
ACG and Mariner, and 16% are gas
reserves mainly related to the Corrib field and the UK part of the Statfjord field.
Proved reserves in Africa
A total of 148 million boe was recognised as proved reserves in PSAs in Angola, Algeria,
 
Nigeria and Libya at year end 2022. Angola
and Algeria are the primary contributors to the proved reserves in this area. Africa
 
represents 3% of Equinor's total proved reserves.
All fields in this area are producing. Net positive revisions increased the proved reserves
 
by 29 million boe in 2022, mainly related to
extended contract and longer technical lifetime on some fields, new wells and positive reservoir
 
performance. Higher commodity
prices decreased the proved reserves in Africa by 20 million boe.
Of total proved reserves in Africa, 131 million boe (88%) are proved developed reserves at year end 2022. Of
 
the total proved
reserves in this area, 89% are liquid reserves mainly related to large oil fields such as Agbami,
 
In Amenas and Murzuq, and 11% are
gas reserves related to the In Salah field.
Proved reserves in the USA
A total of 694 million boe was recognised as proved reserves related to onshore
 
operations and offshore fields in the USA at year end
2022. The USA represents 13% of Equinor's total proved reserves. All fields in this
 
area except for Vito are in the production phase at
year end. Most of the onshore operations and offshore fields in the USA are mature and on decline. New wells
 
extending the proved
areas in the USA onshore assets in 2022, added a total of 89 million boe in the extensions
 
and discoveries category. The proved
reserves in the USA were also subject to a net positive revision of 49 million boe, mainly due to increased
 
activity levels and higher
commodity prices.
Of total proved reserves in the USA, 554 million boe (80%) are proved developed reserves at year
 
end 2022. Of the total proved
reserves in this area, 60% are gas reserves mainly related to the Appalachian basin, and
 
40% are liquid reserves mainly related to the
Appalachian basin and the offshore fields Caesar-Tonga and St. Malo.
exhibit155p11i0 exhibit155p11i1
Equinor 2022 Reserves Report
 
11
Proved reserves in the Americas excluding USA
A total of 538 million boe was recognised as proved reserves in the Americas excluding
 
USA at year end 2022, generally at the same
level as at year end 2021. Three fields are located offshore Brazil, two fields offshore Canada and one field onshore in Argentina.
 
The
Americas excluding USA represents 10% of Equinor's total proved reserves. All fields in this
 
area except for Bacalhau are in the
production phase at year end.
Of total proved reserves in the Americas excluding USA, 220 million boe (41%) are proved
 
developed reserves at year end 2022. Of
the total proved reserves in this area, 99% are liquid reserves mainly related to large oil fields
 
such as Bacalhau, Peregrino and
Roncador, and 1% are gas reserves.
Preparation of reserves estimates
Equinor's annual reporting process for proved reserves is coordinated by a central corporate reserves management
 
(CRM) team
consisting of qualified professionals in geosciences, reservoir and production technology and financial
 
evaluation. The team has an
average of more than 25 years' experience in the oil and gas industry. CRM reports to the senior vice president of accounting and
financial compliance in the Chief financial officer organisation and is independent of the exploration and production
 
business areas. All
the reserves estimates have been prepared by Equinor's technical staff.
Although the CRM team reviews the information centrally, each asset team is responsible for ensuring compliance with the
requirements of the SEC and Equinor's corporate standards. Information about proved oil and gas
 
reserves, standardised measures
of discounted net cash flows related to proved oil and gas reserves and other information related
 
to proved oil and gas reserves, is
collected from the local asset teams and checked by CRM for consistency and conformity with
 
applicable standards. The final
numbers for each asset are quality-controlled and approved by the responsible asset managers,
 
before aggregation to the required
reporting level by CRM.
The person with primary responsibility for overseeing the preparation of the reserves estimates is
 
the manager of the CRM team. The
person who currently holds this position has a bachelor's degree in earth sciences from the University
 
of Gothenburg, and a master's
 
 
 
 
 
 
 
 
Equinor 2022 Reserves Report
 
12
degree in petroleum exploration and exploitation from Chalmers University of Technology in Gothenburg, Sweden. She has 37 years'
experience in the oil and gas industry, 36 of them with Equinor. She is a member of the Society of Petroleum Engineering (SPE) and
of the UNECE Expert Group on Resource Management (EGRM).
DeGolyer and MacNaughton report
Petroleum engineering consultants DeGolyer and MacNaughton have carried out an independent
 
evaluation of Equinor’s
 
proved
reserves as of 31 December 2022 using data provided by Equinor. The evaluation accounts for 100% of Equinor's proved reserves
including equity accounted entities. The aggregated net proved reserves estimates prepared by
 
DeGolyer and MacNaughton do not
differ materially from those prepared by Equinor when compared on the basis of net equivalent barrels.
A report of third party summarising this evaluation is included as Exhibit 15.3 in the annual report
 
on Form 20-F for 2022.
Net proved reserves
Oil and
condensate
NGL/LPG
Natural gas
Oil equivalent
 
At 31 December 2022
(mmboe)
(mmboe)
(mmmcf)
(mmboe)
Estimated by Equinor
2,248
280
14,946
5,191
Estimated by DeGolyer and MacNaughton
2,311
289
15,252
5,318
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor 2022 Reserves Report
 
13
Operational statistics
Developed and undeveloped oil and gas acreage
Total
 
gross and net developed and undeveloped oil and gas acreage, in which Equinor had interests
 
at 31 December 2022, are
presented in the table below.
Total developed and undeveloped oil and gas acreage
At 31 December 2022 (in thousands of acres)
Norway
Eurasia
excluding
Norway
Africa
USA
Americas
excluding
USA
Total
Developed acreage
 
- gross
1)
903
41
846
387
259
2,437
- net
2)
370
14
267
96
63
809
Undeveloped acreage
 
- gross
1)
11,473
1,487
6,006
1,679
22,655
43,300
- net
2)
5,117
751
1,813
656
10,018
18,355
1) A gross value reflects the acreage in which
 
Equinor has a working interest.
2) The net value corresponds to the sum of
 
the fractional working interests owned by
 
Equinor in the same acreage.
Equinor’s largest concentrations of net developed acreage in Norway are
 
in the Troll, Oseberg Area, Snøhvit, Ormen Lange and
Johan Sverdrup fields. In Africa, the Algerian gas development projects In Amenas and In Salah
 
represent the largest concentrations
of net developed acreage. In the USA, the Appalachian basin assets represents the largest net
 
developed acreage.
The largest concentration of net undeveloped acreage is in Argentina, which represents 36% of
 
Equinor’s total net undeveloped
acreage, followed by Norway and Canada.
 
At 31 December 2022, Equinor no longer holds acreage in Russia due to the exit of joint arrangements.
 
Equinor holds acreage in numerous concessions, blocks and leases. The terms and conditions regarding
 
expiration dates vary
significantly from property to property. Work programmes are designed to ensure that the exploration potential of any property is fully
evaluated before expiration.
 
Acreage related to several of these concessions, blocks and leases are scheduled to expire within the
 
next three years. Most of the
undeveloped acreage that will expire within the next three years, is related to early exploration
 
activities where no production is
expected in the foreseeable future. The expiration of these concessions, blocks and leases will
 
therefore not have any material impact
on our proved reserves. Any acreage which has already been evaluated to be non-profitable may be relinquished
 
prior to the current
expiration date. In other cases, Equinor may decide to apply for an extension if more time is
 
needed to fully evaluate the potential of
the properties. Historically, Equinor has generally been successful in obtaining such extensions.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor 2022 Reserves Report
 
14
Productive oil and gas wells
The number of gross and net productive oil and gas wells, in which Equinor had interests
 
at 31 December 2022, are presented in the
table below.
The gross and net number of oil wells has decreased from last year mainly due to the exit of joint
 
arrangements in Russia and the sale
of the Ekofisk Area. The gross and net number of gas wells has increased from last
 
year mainly due to continued drilling in the
Appalachian basin onshore assets in the USA.
The total gross number of productive wells at year end 2022 includes 319 oil wells and 12 gas wells
 
with multiple completions or wells
with more than one branch.
Number of productive oil and gas wells
At 31 December 2022
Norway
Eurasia
excluding
Norway
Africa
USA
Americas
excluding
USA
Total
Oil wells
- gross
1)
776
163
467
75
231
1712
- net
2)
335
37
71
24
68
536
Gas wells
- gross
1)
225
6
115
2421
0
2767
- net
2)
97
2
44
469
0
613
1) A gross value reflects the number of wells in which
 
Equinor owns a working interest.
2) The net value corresponds to the sum of
 
the fractional working interests owned by
 
Equinor in the same gross wells.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor 2022 Reserves Report
 
15
Net productive and dry oil and gas wells drilled
The following table presents the number of net productive and dry exploratory and development oil and
 
gas wells drilled and
completed or abandoned over the past three years. Productive wells include exploratory wells
 
in which hydrocarbons were
discovered, and where drilling or completion has been suspended pending further evaluation. A dry well is
 
a well found to be
incapable of producing sufficient quantities to justify completion as an oil or gas well. Dry development wells
 
are mainly injector wells,
but does also include drilled and permanently abandoned wells.
Number of net productive and dry oil and gas wells drilled
1)
Norway
Eurasia
 
excluding
Norway
Africa
USA
Americas
excluding
USA
Total
Year 2022
Net productive and dry exploratory wells drilled
6.7
-
0.3
0.5
5.1
12.6
- Net dry exploratory wells
4.5
-
0.2
0.5
2.1
7.3
- Net productive exploratory wells
2.2
-
0.1
-
3.0
5.3
Net productive and dry development wells drilled
35.4
5.4
4.0
27.6
12.3
84.7
- Net dry development wells
6.4
1.8
0.9
-
0.1
9.2
- Net productive development wells
28.9
3.6
3.1
27.6
12.2
75.5
Year 2021
Net productive and dry exploratory wells drilled
7.4
0.5
-
-
0.6
8.5
- Net dry exploratory wells
4.0
0.5
-
-
0.6
5.0
- Net productive exploratory wells
3.5
-
-
-
-
3.5
Net productive and dry development wells drilled
38.8
26.6
2.0
19.7
8.5
95.6
- Net dry development wells
8.3
8.6
0.4
-
0.4
17.8
- Net productive development wells
30.5
18.0
1.5
19.7
8.1
77.8
Year 2020
Net productive and dry exploratory wells drilled
8.2
2.0
-
1.1
2.7
14.0
- Net dry exploratory wells
4.7
1.0
-
0.4
0.9
6.9
- Net productive exploratory wells
3.6
1.0
-
0.7
1.8
7.0
Net productive and dry development wells drilled
27.6
22.1
1.6
48.2
8.7
108.2
- Net dry development wells
4.0
3.9
-
-
0.7
8.6
- Net productive development wells
23.6
18.2
1.6
48.2
8.0
99.6
1) The net value corresponds to the sum of the
 
fractional working interests owned by Equinor
 
in the same gross wells.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor 2022 Reserves Report
 
16
Exploratory and development drilling in process
The following table presents the number of gross and net exploratory and development oil and gas wells in the
 
process of being
drilled, or drilled but not yet put on stream at 31 December 2022.
Number of wells in progress
At 31 December 2022
Norway
Eurasia
excluding
Norway
Africa
USA
Americas
excluding
USA
Total
Exploratory wells
- gross
1)
4.0
-
-
1.0
-
5.0
- net
2)
2.2
-
-
0.3
-
2.4
Development wells
- gross
1)
36.0
5.0
7.0
9.0
8.0
65.0
- net
2)
15.7
1.2
2.0
4.0
1.8
24.8
1) A gross value reflects the number of wells
 
in which Equinor owns a working interest.
2) The net value corresponds to the sum of
 
the fractional working interests owned by
 
Equinor in the same gross wells.
Delivery commitments
Equinor is responsible for managing, transporting and selling the Norwegian State's oil and gas from the NCS
 
on behalf of the
Norwegian State's direct financial interest (SDFI). These reserves are sold in conjunction with Equinor’s
 
own reserves. As part of this
arrangement, Equinor delivers gas to customers under various types of sales contracts. In order
 
to meet the commitments, a field
supply schedule is utilised to ensure the highest possible total value for Equinor and SDFI's
 
joint portfolio of oil and gas.
Equinor’s and SDFI's delivery commitments under bilateral agreements for the calendar years
 
2023, 2024, 2025
 
and 2026
 
expressed
as the sum of expected gas off-take, are equal to 43.3, 26.4, 20.2 and 10.6 bcm, respectively. Delivery commitments under bilateral
agreements is declining over time as our customers are increasingly requesting more and more
 
short-term contracts and increased
volumes are traded on the spot market.
Equinor’s currently developed gas reserves on the NCS are more than sufficient to meet
 
our share of these commitments for the next
four years.
Any remaining volumes after covering our delivery commitments under the bilateral agreements, will be sold through
 
trading activities
at the hubs.
Equinor 2022 Reserves Report
 
17
Entitlement production
The following tables present Equinor's Norwegian and international entitlement production of oil, condensate, NGL
 
and natural gas for
the periods indicated. The stated production volumes are the volumes to which Equinor is entitled,
 
pursuant to conditions laid down in
licence agreements and PSAs. The production volumes are net of royalty oil paid in-kind, and of gas used for
 
fuel and flaring.
Production is based on proportionate participation in fields with multiple owners and does not include
 
production of the Norwegian
State's oil and gas. NGL includes both LPG and naphtha. For further information on production volumes
 
see section Terms and
abbreviations.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor 2022 Reserves Report
 
18
Entitlement production
Consolidated companies
Equity accounted
Norway
Eurasia
excluding
Norway
Africa
USA
Americas
excluding
USA
Subtotal
Eurasia
excluding
Norway
Americas
excluding
USA
Subtotal
Total
Oil and condensate (mmboe)
2022
188
11
32
33
23
287
1
3
4
291
2021
200
15
32
37
19
303
5
2
7
310
2020
193
15
39
48
25
320
1
1
2
322
NGL (mmboe)
2022
34
0
2
8
-
45
-
-
-
45
2021
38
0
3
9
-
49
-
-
-
49
2020
40
0
3
11
-
54
-
-
-
54
Natural gas (mmmcf)
2022
1,608
23
28
346
7
2,012
0
2
3
2,015
2021
1,500
20
41
396
8
1,966
3
1
5
1,971
2020
1,425
26
42
373
9
1,874
3
1
3
1,878
Combined oil, condensate, NGL and natural gas (mmboe)
2022
508
16
40
103
24
691
1
3
5
695
2021
505
18
42
117
20
703
6
2
8
710
2020
486
20
49
126
26
708
2
1
3
710
The Troll field in Norway is the only field containing more than 15% of total proved reserves based on barrels
 
of oil equivalent.
 
Troll entitlement production
2022
2021
2020
Troll field
 
Oil and condensate (mmboe)
7
8
9
NGL (mmboe)
2
2
2
Natural gas (mmmcf)
427
403
378
Combined oil, condensate, NGL and natural gas
 
(mmboe)
85
82
79
Equinor 2022 Reserves Report
 
19
Supplementary oil and gas information (unaudited)
In accordance with the US Financial Accounting Standards Board Accounting Standards
 
Codification "Extractive Activities - Oil and
Gas" (Topic 932), Equinor is reporting certain supplemental disclosures about oil and gas exploration and production operations.
While this information is developed with reasonable care and disclosed in good faith, it is
 
emphasised that some of the data is
necessarily imprecise and represents only approximate amounts because of the subjective judgement
 
involved in developing such
information. Accordingly, this information may not necessarily represent the present financial condition of Equinor or its expected
future results.
For further information regarding the reserves estimation requirement, see note 12 Property, plant and equipment - Estimation
uncertainty regarding determining oil and gas reserves and Estimation uncertainty; Proved oil and
 
gas reserves in the annual report
on Form 20-F for 2022.
No events have occurred since 31 December 2022 that would result in a significant change in
 
the estimated proved reserves or other
figures reported as of that date.
Proved oil and gas reserves
Equinor's proved oil and gas reserves have been estimated by its qualified professionals in accordance
 
with industry standards under
the requirements of the US Securities and Exchange Commission (SEC), Rule
 
4-10 of Regulation S-X. Statements of reserves are
forward-looking statements. Proved oil and gas reserves are those quantities of oil and gas, which,
 
by analysis of geoscience and
engineering data, can be estimated with reasonable certainty to be economically producible—from
 
a given date forward, from known
reservoirs, and under existing economic conditions, operating methods, and government regulations—prior
 
to the time at which
contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably
 
certain, regardless of whether
deterministic or probabilistic methods are used for the estimation. The project to extract
 
the hydrocarbons must have commenced or
the operator must be reasonably certain that it will commence the project within a reasonable
 
time.
The determination of these reserves is part of an ongoing process subject to continual revision
 
as additional information becomes
available. Estimates of proved reserve quantities are dynamic and change over time as new information
 
becomes available.
Moreover, identified reserves and contingent resources that may become proved in the future are excluded from the estimates of
proved reserves.
Equinor's proved reserves are recognised under various forms of contractual agreements, including PSAs
 
where Equinor's share of
reserves can vary due to commodity prices or other factors. Reserves from agreements such as
 
PSAs are based on the volumes to
which Equinor has access (cost oil and profit oil), limited to available market access. At 31 December
 
2022, 5%
of total proved
reserves were related to such agreements, representing 10% of the oil, condensate and NGL reserves
 
and 1% of the gas reserves.
This compares with 6% and 5% of total proved reserves for 2021 and 2020, respectively. Net entitlement oil and gas production from
fields with such agreements was 44 million boe during 2022, compared to 49 million boe for 2021 and
 
59 million boe for 2020. Equinor
participates in such agreements in Algeria, Angola, Azerbaijan, Brazil, Libya and Nigeria.
Equinor is recording, as proved reserves, volumes equivalent to our tax liabilities under negotiated fiscal
 
arrangements (PSAs) where
the tax is paid on behalf of Equinor. Reserves
 
are net of royalty volumes in the USA and net of royalty paid in-kind in PSA fields.
Proved reserves does not include quantities consumed during production.
Rule 4-10 of Regulation S-X requires that the estimation of reserves shall be based on existing economic
 
conditions, including a 12-
month average price determined as an unweighted arithmetic average of the first-of-the month price for each month
 
within the
reporting period, unless prices are defined by contractual arrangements. Volume weighted average prices for the total Equinor
portfolio, and the Brent blend price, are presented in the following table:
 
 
 
 
 
 
 
 
 
Equinor 2022 Reserves Report
 
20
Volume weighted average prices
 
at 31 December
Brent blend
Oil
Condensate
NGL
Natural gas
 
(USD/boe)
(USD/boe)
(USD/boe)
(USD/boe)
(USD/mmbtu)
2022
101.24
100.30
90.79
56.23
30.66
2021
69.22
67.61
65.02
47.17
11.89
2020
41.26
40.60
33.99
23.72
3.18
Higher commodity prices affected the profitable reserves to be recovered from accumulations, resulting in increased
 
proved reserves.
The positive revisions due to higher price are in general a result of later economic cut-off. For fields with a PSA
 
the effect of higher
prices is to some degree offset
 
by reduced entitlement to the reserves. These changes are all included in the revision category, giving
a net increase of Equinor’s proved reserves at year end.
From the NCS, Equinor is responsible for managing, transporting and selling the Norwegian State's
 
oil and gas on behalf of the
Norwegian State's direct financial interest (SDFI). These reserves are sold in conjunction with
 
the Equinor reserves. As part of this
arrangement, Equinor delivers and sells gas to customers in accordance with various types of sales
 
contracts on behalf of the SDFI.
In order to fulfil the commitments, Equinor utilises a field supply schedule which provides the highest
 
possible total value for the joint
portfolio of oil and gas between Equinor and the SDFI.
Equinor and the SDFI receive income from the joint gas sales portfolio based upon their respective
 
share in the supplied volumes. For
sales of the SDFI gas, to Equinor and to third parties, the payment to the Norwegian State is
 
based on achieved prices, a net back
formula calculated price or market value. All of the Norwegian State's oil and NGL is acquired by Equinor. The price Equinor pays to
the SDFI for the crude oil is based on market reflective prices. The prices for NGL
 
are either based on achieved prices, market value
or market reflective prices. The regulations of the owner's instruction may be changed or withdrawn
 
by the Equinor ASA's general
meeting.
Topic 932 requires the presentation of reserves and certain other supplemental oil and gas disclosures by geographic area, defined
as country or continent containing 15% or more of total proved reserves. At 31 December 2022,
 
Norway is the only country in this
category, with 71% of the total proved reserves. The USA contains close to 15% of the total proved reserves at 31 December 2022
and has been close to this level for several years. Management has therefore determined that
 
the most meaningful presentation of
geographical areas in 2022 would be Norway, the USA, and the continents of Eurasia excluding Norway, Africa, and Americas
excluding USA.
Proved reserves movements
The largest relative changes in the proved reserves within a geographic area compared to the
 
previous year for each of the last three
years, are summarised below. All changes in the Net proved reserves (in million boe) table that represent 10% or more of the net
proved reserves in million boe at the beginning of each year are discussed.
Proved reserves movements 2022
Eurasia excluding Norway
The net decrease of 14 million boe in revisions and improved recovery in Eurasia excluding
 
Norway is the combined effect of mainly
negative revisions based on reduced production potential, and reduced entitlement volumes resulting from
 
higher commodity prices.
Purchase of the UK part of the Statfjord field is the main reason for the increase of 15 million
 
boe through purchases of reserves-in-
place in this area. Exit from our Russian joint arrangements reduced the proved reserves in
 
both consolidated (10 million boe) and
equity accounted (76 million boe) companies and is included as a sales of reserves-in-place.
Africa
The net effect of revisions and improved recovery of 29 million boe in Africa is the combined effect of 46 million
 
boe in positive
revisions resulting from both longer economic lifetime with higher commodity prices as well as extended contract
 
and longer technical
lifetime on some fields, and negative revisions of 17 million boe related to reduced entitlement
 
volumes with higher commodity prices.
 
USA
The increase of 89 million boe in extensions and discoveries in the USA is the result of new wells
 
drilled in previously unproven areas
in our onshore developments in the Appalachian basin assets.
Americas excluding USA
The increase of 9 million boe in extensions and discoveries in the Americas excluding USA
 
is the result of new wells drilled in
previously unproven areas in our onshore developments in Argentina.
Proved reserves movements 2021
Norway
Equinor 2022 Reserves Report
 
21
The increase of 465 million boe in revisions and improved recovery in Norway was the combined
 
effect of positive revisions following
increased certainty in the ultimate recovery at many fields, prolonged economic lifetime at
 
several fields due to higher commodity
prices, and decisions to install low pressure production facilities increasing the future recovery at
 
the Oseberg and Ormen Lange
fields.
Eurasia excluding Norway
The net decrease of 16 million boe in equity accounted assets in the revisions and improved recovery
 
category was related to proved
reserves in Russia, where negative revisions of 35 million boe due to reduced production
 
potential in some areas was partially offset
by positive revisions based on increased certainty in the expected ultimate recovery in other areas.
USA
The increase of 78 million boe in revisions and improved recovery was the combined effect of positive revisions following increased
certainty in the ultimate recovery, and prolonged economic lifetime at several fields mainly due to higher commodity prices. Sales of
reserves-in-place of 89 million boe was a result of the divestment of our interests in the Bakken
 
assets which was completed in 2021.
Americas excluding USA
The increase of 62 million boe in revisions and improved recovery was mainly related to proved reserves
 
in Brazil and is the combined
effect of positive revisions following increased certainty in the ultimate recovery, and prolonged economic lifetime due to higher
commodity prices. The increase of 210 million boe in extensions and discoveries was the result of sanctioning
 
of the Bacalhau
development in Brazil, and the 14 million boe of equity accounted additions in the same
 
category represent drilling of new wells in
previously unproven areas at the Bandurria Sur development in Argentina.
Proved reserves movements 2020
Africa
The net increase of 40 mill boe in revision and improved recovery was mainly due to positive revisions
 
on several fields with PSAs in
Angola, Algeria, Nigeria and Libya.
 
USA
The net decrease of 118 million boe in revisions and improved recovery included a negative revision of 110 million boe related to our
onshore developments. This was mainly due to reduced activity levels as well as shorter economic field
 
lifetime caused by lower oil
and gas prices. The lower prices have also affected some of our Gulf of Mexico fields negatively. The increase of 101 million boe in
extension and discoveries was the result of new wells drilled in previously unproven areas in
 
our onshore developments.
Americas excl USA
The net decrease of 55 million boe in revisions and improved recovery was mainly due to shorter economic lifetime
 
for fields in Brazil
caused by lower oil prices. The equity accounted increase of 6 million boe in purchases of reserves-in-place
 
is in Argentina.
The following tables reflect the estimated oil, condensate, NGL and natural gas proved reserves
 
at 31 December 2019 through 2022
and the changes therein.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor 2022 Reserves Report
 
22
Consolidated companies
Equity accounted
Net proved oil and condensate
reserves
(in million boe)
Norway
Eurasia
excludin
g
Norway
Africa
USA
America
s
excludin
g USA
Subtotal
Eurasia
excludin
g
Norway
America
s
excludin
g USA
Subtotal
Total
At 31 December 2019
1,463
168
137
383
369
2,518
56
-
56
2,575
Revisions and improved recovery
32
(12)
33
(55)
(57)
(58)
(5)
-
(5)
(63)
Extensions and discoveries
27
2
-
7
-
36
0
-
0
36
Purchases of reserves-in-place
-
-
-
-
-
-
-
5
5
5
Sales of reserves-in-place
-
-
-
-
-
-
-
-
-
-
Production
(193)
(15)
(39)
(48)
(25)
(320)
(1)
(1)
(2)
(322)
At 31 December 2020
1,329
143
131
287
287
2,177
50
5
55
2,232
Revisions and improved recovery
153
(15)
18
23
61
240
17
0
17
257
Extensions and discoveries
14
0
-
1
210
225
2
12
14
239
Purchases of reserves-in-place
-
-
-
-
-
-
-
-
-
-
Sales of reserves-in-place
-
-
-
(57)
(6)
(63)
-
-
-
(63)
Production
(200)
(15)
(32)
(37)
(19)
(303)
(5)
(2)
(7)
(310)
At 31 December 2021
1,296
114
116
217
533
2,276
64
15
79
2,355
Revisions and improved recovery
133
(15)
40
32
3
192
0
(0)
(0)
192
Extensions and discoveries
67
-
-
1
-
68
-
7
7
75
Purchases of reserves-in-place
10
5
-
-
-
15
-
-
-
15
Sales of reserves-in-place
(25)
(10)
-
-
-
(35)
(62)
-
(62)
(97)
Production
(188)
(11)
(32)
(33)
(23)
(287)
(1)
(3)
(4)
(291)
At 31 December 2022
1,292
83
123
217
513
2,228
-
19
19
2,248
Proved developed oil and
condensate reserves
At 31 December 2019
691
44
124
278
254
1,392
5
-
5
1,396
At 31 December 2020
654
54
110
217
202
1,237
8
5
13
1,249
At 31 December 2021
702
47
104
161
205
1,218
22
10
31
1,249
At 31 December 2022
731
35
107
161
203
1,236
-
12
12
1,249
Proved undeveloped oil and
condensate reserves
At 31 December 2019
772
123
13
104
115
1,127
52
-
52
1,178
At 31 December 2020
676
88
21
70
86
940
42
0
42
982
At 31 December 2021
594
67
13
56
328
1,058
42
5
47
1,105
At 31 December 2022
562
48
17
56
309
992
-
7
7
999
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor 2022 Reserves Report
 
23
Consolidated companies
Equity accounted
Net proved NGL reserves
 
(in million boe)
Norway
Eurasia
excludin
g
Norway
Africa
USA
America
s
excludin
g USA
Subtotal
Eurasia
excludin
g
Norway
America
s
excludin
g USA
Subtotal
Total
At 31 December 2019
254
-
18
65
-
337
-
-
-
337
Revisions and improved recovery
(7)
0
2
(8)
-
(13)
-
-
-
(13)
Extensions and discoveries
0
-
-
7
-
8
-
-
-
8
Purchases of reserves-in-place
-
-
-
-
-
-
-
-
-
-
Sales of reserves-in-place
-
-
-
-
-
-
-
-
-
-
Production
(40)
(0)
(3)
(11)
-
(54)
-
-
-
(54)
At 31 December 2020
208
0
17
53
-
278
-
-
-
278
Revisions and improved recovery
31
0
(1)
14
-
44
-
-
-
44
Extensions and discoveries
1
-
-
4
-
5
-
-
-
5
Purchases of reserves-in-place
-
-
-
-
-
-
-
-
-
-
Sales of reserves-in-place
-
-
-
(17)
-
(17)
-
-
-
(17)
Production
(38)
(0)
(3)
(9)
-
(49)
-
-
-
(49)
At 31 December 2021
202
0
14
45
-
261
-
-
-
261
Revisions and improved recovery
13
0
(3)
13
-
23
-
-
-
23
Extensions and discoveries
26
-
-
10
-
37
-
-
-
37
Purchases of reserves-in-place
4
3
-
-
-
7
-
-
-
7
Sales of reserves-in-place
(3)
-
-
-
-
(3)
-
-
-
(3)
Production
(34)
(0)
(2)
(8)
-
(45)
-
-
-
(45)
At 31 December 2022
209
3
8
60
-
280
-
-
-
280
Proved developed NGL reserves
At 31 December 2019
175
-
15
49
-
240
-
-
-
240
At 31 December 2020
141
0
15
47
-
204
-
-
-
204
At 31 December 2021
160
0
12
37
-
209
-
-
-
209
At 31 December 2022
149
3
8
51
-
210
-
-
-
210
Proved undeveloped NGL
reserves
At 31 December 2019
78
-
3
16
-
97
-
-
-
97
At 31 December 2020
66
(0)
2
6
-
74
-
-
-
74
At 31 December 2021
42
-
2
8
-
52
-
-
-
52
At 31 December 2022
60
0
0
9
-
70
-
-
-
70
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor 2022 Reserves Report
 
24
Consolidated companies
Equity accounted
Net proved
 
natural gas reserves
 
(in billion cf)
Norway
Eurasia
excludin
g
Norway
Africa
USA
America
s
excludin
g USA
Subtotal
Norway
Eurasia
excludin
g
Norway
America
s
excludin
g USA
Subtotal
Total
At 31 December 2019
14,330
111
241
2,371
8
17,060
-
295
-
295
17,355
Revisions and improved
recovery
(195)
(36)
29
(311)
8
(505)
-
(28)
-
(28)
(534)
Extensions and discoveries
4
-
-
485
-
488
-
-
-
-
488
Purchases of reserves-in-
place
-
-
-
-
-
-
-
-
4
4
4
Sales of reserves-in-place
-
-
-
-
-
-
-
-
-
-
-
Production
(1,425)
(26)
(42)
(373)
(9)
(1,874)
-
(3)
(1)
(3)
(1,878)
At 31 December 2020
12,714
49
227
2,171
7
15,169
-
264
3
267
15,436
Revisions and improved
recovery
1,576
46
(23)
231
7
1,837
-
(183)
1
(182)
1,656
Extensions and discoveries
23
-
-
313
-
337
-
-
11
11
348
Purchases of reserves-in-
place
-
-
-
-
-
-
-
-
-
-
-
Sales of reserves-in-place
-
-
-
(87)
-
(87)
-
-
-
-
(87)
Production
(1,500)
(20)
(41)
(396)
(8)
(1,966)
-
(3)
(1)
(5)
(1,971)
At 31 December 2021
12,813
75
163
2,233
6
15,289
-
78
14
92
15,381
Revisions and improved
recovery
720
3
(44)
23
11
713
-
0
6
6
720
Extensions and discoveries
494
-
-
434
-
928
-
-
9
9
937
Purchases of reserves-in-
place
41
40
-
-
-
81
-
-
-
-
81
Sales of reserves-in-place
(79)
-
-
-
-
(79)
-
(78)
-
(78)
(157)
Production
(1,608)
(23)
(28)
(346)
(7)
(2,012)
-
(0)
(2)
(3)
(2,015)
At 31 December 2022
12,380
94
91
2,344
10
14,920
-
-
26
26
14,946
Proved developed natural
gas reserves
At 31 December 2019
9,417
111
217
1,645
8
11,398
-
67
-
67
11,465
At 31 December 2020
7,863
49
199
1,681
7
9,799
-
123
3
126
9,926
At 31 December 2021
11,145
75
145
1,845
5
13,217
-
19
9
28
13,244
At 31 December 2022
10,294
89
91
1,921
8
12,403
-
-
17
17
12,420
Proved undeveloped natural
gas reserves
At 31 December 2019
4,912
0
23
726
-
5,662
-
228
-
228
5,889
At 31 December 2020
4,851
0
28
490
-
5,369
-
141
0
141
5,510
At 31 December 2021
1,667
-
17
387
0
2,072
-
59
5
64
2,136
At 31 December 2022
2,087
5
-
423
2
2,517
-
-
9
9
2,526
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor 2022 Reserves Report
 
25
Consolidated companies
Equity accounted
Net proved reserves
 
(in million boe)
Norway
Eurasia
excludin
g
Norway
Africa
USA
America
s
excludin
g USA
Subtotal
Eurasia
excludin
g
Norway
America
s
excludin
g USA
Subtotal
Total
At 31 December 2019
4,270
187
198
870
370
5,895
109
-
109
6,004
Revisions and improved recovery
(9)
(18)
40
(118)
(55)
(161)
(10)
-
(10)
(171)
Extensions and discoveries
28
2
-
101
-
131
0
-
0
131
Purchases of reserves-in-place
-
-
-
-
-
-
-
6
6
6
Sales of reserves-in-place
-
-
-
-
-
-
-
-
-
-
Production
(486)
(20)
(49)
(126)
(26)
(708)
(2)
(1)
(3)
(710)
At 31 December 2020
3,802
151
189
727
289
5,158
97
5
102
5,260
Revisions and improved recovery
465
(6)
13
78
62
611
(16)
1
(15)
596
Extensions and discoveries
19
0
-
61
210
290
2
14
16
306
Purchases of reserves-in-place
-
-
-
-
-
-
-
-
-
-
Sales of reserves-in-place
-
-
-
(89)
(6)
(96)
-
-
-
(96)
Production
(505)
(18)
(42)
(117)
(20)
(703)
(6)
(2)
(8)
(710)
At 31 December 2021
3,781
127
159
660
534
5,261
77
18
95
5,356
Revisions and improved recovery
275
(14)
29
49
4
343
0
1
1
344
Extensions and discoveries
181
-
-
89
-
269
-
9
9
278
Purchases of reserves-in-place
21
15
-
-
-
36
-
-
-
36
Sales of reserves-in-place
(42)
(10)
-
-
-
(52)
(76)
-
(76)
(128)
Production
(508)
(16)
(40)
(103)
(24)
(691)
(1)
(3)
(5)
(695)
At 31 December 2022
3,708
103
148
694
514
5,167
-
24
24
5,191
Proved developed reserves
At 31 December 2019
2,544
64
178
621
255
3,663
17
-
17
3,679
At 31 December 2020
2,196
63
161
564
203
3,187
30
5
35
3,222
At 31 December 2021
2,847
60
141
527
206
3,782
25
12
36
3,818
At 31 December 2022
2,714
53
131
554
205
3,656
-
16
16
3,672
Proved undeveloped reserves
At 31 December 2019
1,725
123
20
250
115
2,233
92
-
92
2,325
At 31 December 2020
1,606
88
28
163
86
1,971
67
0
67
2,038
At 31 December 2021
934
67
18
133
328
1,479
53
6
59
1,538
At 31 December 2022
994
50
17
140
310
1,510
-
9
9
1,519
The conversion rates used in this table are 1 standard cubic meter = 35.3 standard cubic
 
feet, 1 standard cubic meter oil equivalent =
6.29 barrels of oil equivalent (boe) and 1,000 standard cubic meter gas = 1 standard cubic meter oil equivalent.
Standardised measure of discounted future net cash flows relating to proved oil
 
and gas reserves
Equinor 2022 Reserves Report
 
26
The table below shows the standardised measure of future net cash flows relating to
 
proved reserves. The analysis is computed in
accordance with Topic 932, by applying average market prices as defined by the SEC, year end costs, year end statutory tax rates
and a discount factor of 10% to year end quantities of net proved reserves. The standardised
 
measure of discounted future net cash
flows is a forward-looking statement.
Future price changes are limited to those provided by existing contractual arrangements at the
 
end of each reporting year. Future
development and production costs are those estimated future expenditures necessary to
 
develop and produce year end estimated
proved reserves based on year end cost indices, assuming continuation of year end economic conditions.
 
Pre-tax future net cash flow
is net of decommissioning and removal costs. Estimated future income taxes are calculated
 
by applying the appropriate year end
statutory tax rates. These rates reflect allowable deductions and tax credits and are applied to
 
estimated future pre-tax net cash flows,
less the tax basis of related assets. Discounted future net cash flows are calculated using a discount
 
rate of 10% per year.
Discounting requires a year-by-year estimate of when future expenditures will be incurred and when
 
reserves will be produced. The
standardised measure of discounted future net cash flows prescribed under Topic 932 requires assumptions as to the timing and
amount of future development and production costs and income from the production of proved reserves. The
 
information does not
represent management's estimate or Equinor's expected future cash flows or the value of its proved reserves
 
and therefore should not
be relied upon as an indication of Equinor’s future cash flow or value of its proved
 
reserves.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor 2022 Reserves Report
 
27
At 31 December 2022
(in USD million)
Norway
Eurasia
excluding
Norway
Africa
USA
Americas
excluding
USA
Total
Consolidated companies
Future net cash inflows
620,024
11,225
13,955
35,382
50,744
731,330
Future development costs
(15,595)
(1,795)
(1,012)
(1,388)
(3,830)
(23,620)
Future production costs
(60,837)
(4,356)
(3,706)
(8,736)
(19,807)
(97,442)
Future income tax expenses
(449,351)
(1,725)
(3,864)
(5,402)
(5,122)
(465,465)
Future net cash flows
94,241
3,348
5,374
19,855
21,984
144,803
10% annual discount for estimated timing of
 
cash flows
(36,714)
(954)
(1,275)
(7,124)
(10,633)
(56,701)
Standardised measure of discounted future net
 
cash flows
57,527
2,394
4,099
12,731
11,351
88,102
Equity accounted investments
Standardised measure of discounted future net
 
cash flows
-
-
-
-
316
316
Total standardised measure of discounted future net cash
flows including equity accounted investments
57,527
2,394
4,099
12,731
11,667
88,418
At 31 December 2021
(in USD million)
Norway
Eurasia
excluding
Norway
Africa
USA
Americas
excluding
USA
Total
Consolidated companies
Future net cash inflows
287,382
8,705
9,619
21,486
35,236
362,429
Future development costs
(10,999)
(1,947)
(685)
(1,112)
(4,186)
(18,928)
Future production costs
(53,251)
(4,196)
(3,380)
(7,269)
(16,782)
(84,878)
Future income tax expenses
(178,370)
(352)
(2,138)
(2,686)
(2,979)
(186,525)
Future net cash flows
44,763
2,209
3,416
10,420
11,289
72,097
10% annual discount for estimated timing of
 
cash flows
(18,051)
(652)
(707)
(3,406)
(5,842)
(28,658)
Standardised measure of discounted future net
 
cash flows
26,711
1,557
2,709
7,014
5,447
43,439
Equity accounted investments
Standardised measure of discounted future net
 
cash flows
-
224
-
-
126
350
Total standardised measure of discounted future net cash
flows including equity accounted investments
26,711
1,782
2,709
7,014
5,573
43,789
At 31 December 2020
(in USD million)
Norway
Eurasia
excluding
Norway
Africa
USA
Americas
excluding
USA
Total
Consolidated companies
Future net cash inflows
107,618
6,610
7,234
14,892
10,685
147,039
Future development costs
(11,209)
(2,489)
(682)
(1,351)
(1,534)
(17,265)
Future production costs
(42,410)
(3,622)
(3,170)
(8,020)
(7,568)
(64,790)
Future income tax expenses
(35,236)
(209)
(1,262)
(965)
(336)
(38,008)
Future net cash flows
18,763
290
2,119
4,556
1,248
26,976
10% annual discount for estimated timing of
 
cash flows
(6,937)
(80)
(505)
(1,269)
24
(8,768)
Standardised measure of discounted future net cash
 
flows
11,826
210
1,614
3,286
1,272
18,209
Equity accounted investments
Standardised measure of discounted future net
 
cash flows
-
(32)
-
-
22
(10)
 
 
 
Equinor 2022 Reserves Report
 
28
Total standardised measure of discounted future net cash
flows including equity accounted investments
11,826
178
1,614
3,286
1,294
18,199
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Equinor 2022 Reserves Report
 
29
Changes in the standardised measure of discounted
 
future net cash flows from proved reserves
(in USD million)
2022
2021
2020
Consolidated companies
Standardised measure at 1 January
43,439
18,209
35,173
Net change in sales and transfer prices and in production
 
(lifting) costs related to future production
231,555
126,974
(52,527)
Changes in estimated future development costs
(4,739)
(5,915)
(1,547)
Sales and transfers of oil and gas produced
 
during the period, net of production cost
(91,580)
(43,998)
(15,180)
Net change due to extensions, discoveries,
 
and improved recovery
15,928
7,734
265
Net change due to purchases and sales of minerals
 
in place
386
(2,280)
-
Net change due to revisions in quantity estimates
34,325
17,080
3,263
Previously estimated development costs incurred during
 
the period
6,691
6,619
6,558
Accretion of discount
15,063
4,078
9,087
Net change in income taxes
(162,965)
(85,062)
33,117
Total change in the standardised measure during the year
44,663
25,230
(16,965)
Standardised measure at 31 December
88,102
43,439
18,209
Equity accounted investments
Standardised measure at 31 December
316
350
(10)
Standardised measure at 31 December including
 
equity accounted investments
88,418
43,789
18,199
In this table each line item presents the sources of changes in the standardised measure of value
 
on a discounted basis, with the
accretion of discount line item reflecting the increase in the net discounted value of the proved
 
oil and gas reserves due to the fact that
the future cash flows are now one year closer in time.
The standardised measure at the beginning of the year represents the discounted net present value
 
after deductions of both future
development costs, production costs and taxes. The line item Net change in sales and transfer
 
prices and in production (lifting) costs
related to future production is, on the other hand, related to the future net cash flows
 
at 31 December 2021. The proved reserves at 31
December 2021 were multiplied by the actual change in price, and change in unit of production costs,
 
to arrive at the net effect of
changes in price and production costs. Development costs and taxes are reflected in the
 
line items Change in estimated future
development costs and Net change in income taxes and are not included in the Net change
 
in sales and transfer prices and in
production (lifting) costs related to future production.
Equinor 2022 Reserves Report
 
30
Terms
 
and abbreviations
Organisational abbreviations
 
●
 
ACG - Azeri-Chirag-Gunashli
●
 
CAPEX - Capital expenditure
●
 
IOR - Improved oil recovery
●
 
LPG - Liquefied petroleum gas
●
 
NCS - Norwegian continental shelf
●
 
NGL - Natural gas liquids
●
 
OECD - Organisation of Economic Co-Operation and
 
Development
●
 
PDO - Plan for development and operation
●
 
PSA - Production sharing agreement
●
 
SDFI - Norwegian State's Direct Financial Interest
●
 
SEC - US Securities and Exchange Commission
●
 
UKCS - UK continental shelf
●
 
USA - United States of America
●
 
USD - United States dollar
Measurement abbreviations etc.
●
 
one billion - one thousand million
●
 
bbl - barrel
●
 
mmbbl - million barrels
●
 
boe - barrels of oil equivalent
●
 
mmboe - million barrels
 
of oil equivalent
●
 
cf - cubic feet
●
 
mmmcf - billion cubic feet
●
 
MMBtu - million british thermal units
●
 
bcm - billion cubic metres of natural gas
Equivalent measurements are based upon
●
 
1 barrel equals 0.134 tonnes of oil (33 degrees
 
API)
●
 
1 barrel equals 0.159 standard cubic metres
●
 
1 barrel of oil equivalent equals 1 barrel
 
of crude oil
●
 
1 barrel of oil equivalent equals 159 standard
 
cubic metres of natural gas
●
 
1 barrel of oil equivalent equals 5,612 cubic
 
feet of natural gas
●
 
1 barrel of oil equivalent equals 0.0837 tonnes of
 
NGLs
●
 
1 billion standard cubic metres of natural gas equals
 
1 million standard cubic metres of oil equivalent
●
 
1 cubic metre equals 35.3 cubic feet
●
 
1 cubic metre of natural gas equals 1 standard
 
cubic metre of natural gas
●
 
1,000 standard cubic meter gas equals 1 standard
 
cubic meter oil equivalent
●
 
1,000 standard cubic metres of natural gas equals
 
6.29 boe
●
 
1 standard cubic foot equals 0.0283 standard
 
cubic metres
●
 
1 standard cubic foot equals 1000 British thermal units
 
(btu)
●
 
1 tonne of NGLs equals 1.9 standard
 
cubic metres of oil equivalent
Miscellaneous terms
●
 
Appraisal well: A well drilled to establish the extent
 
and the size of a discovery.
●
 
BOE (barrels of oil equivalent): A measure
 
to quantify crude oil, natural gas liquids and natural
 
gas amounts using the same basis.
Natural gas volumes are converted to barrels on
 
the basis of energy content.
●
 
Condensates: The heavier natural gas components,
 
such as pentane, hexane, iceptane and so
 
forth, which are liquid under atmospheric
pressure – also called natural gasoline or naphtha.
●
 
Development: The drilling, construction, and related activities
 
following discovery that are necessary to
 
begin production of crude oil and
natural gas fields.
●
 
Equity and entitlement volumes of oil and gas:
 
Equity volumes represent volumes produced under
 
a production sharing agreement (PSA)
that correspond to Equinor's percentage ownership in
 
a particular field. Entitlement volumes, on the other
 
hand, represent Equinor's
share of the volumes distributed to the partners in
 
the field, which are subject to deductions
 
for, among other things, royalties and the
host government's share of profit oil. Under
 
the terms of a PSA, the amount of profit oil deducted
 
from equity volumes will normally
increase with the cumulative return on investment
 
to the partners and/or production from the
 
licence. The distinction between equity and
entitlement is relevant to most PSA regimes, whereas
 
it is not applicable in most concessionary regimes
 
such as those in Norway, the
United Kingdom,
 
Canada and Brazil. The overview of equity production
 
provides additional information for readers, as certain
 
costs
described in the profit and loss analysis were
 
directly associated with equity volumes produced
 
during the reported years.
●
 
IOR (improved oil recovery): Actual measures resulting
 
in an increased oil recovery factor from
 
a reservoir as compared with the
expected value at a certain reference point in time.
 
IOR comprises both of conventional and emerging
 
technologies.
●
 
Liquids: Refers to oil, condensates and NGL.
Equinor 2022 Reserves Report
 
31
●
 
LPG (liquefied petroleum gas): Consists primarily
 
of propane and butane, which turn liquid under
 
a pressure of six to seven atmospheres.
LPG is shipped in special vessels.
●
 
Natural gas: Petroleum that consists principally of
 
light hydrocarbons. It can be divided into 1)
 
lean gas, primarily methane but often
containing some ethane and smaller quantities of
 
heavier hydrocarbons (also called sales gas) and
 
2) wet gas, primarily ethane, propane
and butane as well as smaller amounts of heavier
 
hydrocarbons; partially liquid under atmospheric
 
pressure.
●
 
NGL (natural gas liquids): Light hydrocarbons mainly
 
consisting of ethane, propane and butane which
 
are liquid under pressure at normal
temperature.
●
 
Petroleum: A collective term for hydrocarbons, whether
 
solid, liquid or gaseous. Hydrocarbons are compounds
 
formed from the elements
hydrogen (H) and carbon (C). The proportion
 
of different compounds, from methane and ethane up
 
to the heaviest components, in a
petroleum find varies from discovery to discovery. If a reservoir primarily contains
 
light hydrocarbons, it is described as a gas field.
 
If
heavier hydrocarbons predominate, it is described
 
as an oil field. An oil field may feature free gas
 
above the oil and contain a quantity of
light hydrocarbons, also called associated gas.
●
 
Proved reserves: Reserves claimed to have a
 
reasonable certainty (normally at least 90% confidence)
 
of being recoverable under
existing economic and political conditions and using
 
existing technology. They are the only type the US Securities and Exchange
Commission allows oil companies to report.
1
Equinor remuneration report for 2022
Corporate executive committee, board of directors and corporate
 
assembly
Contents
2
1
 
Preamble
 
1.1
 
Introduction
The remuneration report contains information on:
 
-
 
the remuneration for Equinor’s corporate executive
 
committee (“CEC”) consisting of the chief
executive officer (“CEO”) and the executive vice presidents (“EVPs”)
-
 
the remuneration for Equinor’s corporate assembly and board
 
of directors (“the board”)
 
The remuneration report is proposed by the board of directors, where
 
an advisory vote shall be held by
the 2023 annual general meeting (“AGM”), pursuant to the Norwegian
 
Public Limited Liability
Companies Act, section 6-16b and regulation 2020-12-
11
-2730 and the Norwegian Accounting Act
section 7-31b.
The remuneration report should be read in conjunction with the remuneration
 
policy,
 
which is included
in the Appendix.
 
1.2
 
Letter from the chair of the board of directors
On behalf of the board of directors, I present to you Equinor’s
 
remuneration report for 2022. Our
objective is to provide a comprehensive and transparent overview
 
of the remuneration of the board of
directors, the corporate assembly and the corporate executive committee
 
in 2022.
 
 
 
 
3
Equinor in 2022
The role of Equinor as a reliable energy provider is more important
 
than ever. The Russian war in
Ukraine has changed the energy markets, reduced energy
 
availability and increased prices. Equinor
continued to provide stable flow and record-level production in
 
2022, with an increased focus on safety
in a challenging global environment. High production combined with high
 
price levels resulted in very
strong financial results.
 
Developing new solutions for the energy transition remained a high
 
priority in 2022. Equinor continued
strengthening workforce capacity and capabilities both on the Norwegian
 
continental shelf and in
locations around the world, ramping up recruitment, strengthening
 
learning activities and focusing on
diversity, inclusion and wellbeing.
More details on Equinor’s performance results within
 
the different perspectives of our performance
assessment are presented further in this report and in Equinor’s
 
annual report.
Work on improving the information in the remuneration policy and
 
remuneration report
The Norwegian Ministry of Trade, Industry and Fisheries (“MTIF”) that represents Equinor’s
 
majority
shareholder issued a statement to Equinor which was presented at
 
the 2022
 
annual general meeting,
as follows:
 
The Ministry of Trade,
 
Industry and Fisheries (MTIF) refers to the State’s
 
Guidelines for the Remuneration of
Senior Executives in Companies with State Ownership
 
stipulated on 20 April 2021. The MTIF wants to emphasise
the state’s expectations in the executive remuneration
 
area, including paying due regard to the principle of
moderation. The state finds it important that the remuneration
 
of senior executives is competitive, enabling the
company to succeed in recruiting and retaining good executives.
 
At the same time the remuneration shall not be
market-leading compared with similar companies, and shall be
 
set with due regard to the principle of moderation.
This, among other things, means that the remuneration
 
shall not be higher than necessary to attract and retain the
desired expertise. It is neither in the interest of the company,
 
nor the owners, if the company pays more
remuneration, including bonus, than necessary.
 
When evaluating moderation, the ratio between the remuneration
of executive personnel and other employees in the company
 
may be relevant. The state finds it important that this
ratio does not increase without a good justification. Increased
 
difference in the remuneration between executive
personnel and other employees in the company may be ill-judged,
 
among other things because it may be harmful
to the company’s reputation by contributing to
 
unreasonable disparities in the company and society at
 
large. The
state finds it important that the board pays due regard
 
to the principle of moderation in determining the total
remuneration. The state, as an owner,
 
emphasises transparency associated with executive remuneration.
Transparency as regards
 
the formulation, level and development of executive remuneration,
 
including that that the
programmes are unambiguous, is important in order to
 
enable owners and other stakeholders to evaluate the
executive remuneration. The state, as an owner,
 
will continue the dialogue with Equinor about how the
 
board of
directors’ executive remuneration policy can be better aligned with
 
the state’s expectations in the executive
remuneration area, and expects the board of directors
 
to present an updated policy for the 2023 annual general
meeting.
Over the course of 2022, Equinor worked on revising the remuneration
 
policy and remuneration report
to address the expectations in the above note, with a particular
 
focus on clarifying the application of the
pay-for-performance approach, paying due regard to the principle
 
of moderation and ensuring
transparency in the formulation and level of executive remuneration.
 
The review also included
adjustments to the structure, wording and presentation of the information
 
contained in the remuneration
policy and remuneration report, aiming for a more logical, modern and
 
user-friendly style for the reader.
As of 2022 the remuneration report is presented as a stand-alone document,
 
separate to Equinor’s
annual report.
 
The new remuneration policy is presented for the 2023 AGM for approval
 
and will be effective as of the
reporting year 2024. The 2022 report is therefore based on the
 
remuneration policy approved in the
2021 AGM.
4
Equinor executive performance and remuneration in 2022
The general salary increases for the members of the CEC in 2022
 
were in line with the general salary
increase frame in the relevant Equinor entity.
 
Equinor’s strong financial and operational performance
 
in 2022, as well as a strong position compared
to peers was reflected in the annual variable pay awards.
An important focus area in 2022 was improving the clarity and consistency
 
in documenting the targets
for measuring the performance of the CEC members. Individual
 
performance contracts are in place as
of 2022 outlining the respective KPIs and goals used as a basis for assessing
 
results and translating
those into annual variable pay awards.
On 12 December,
 
the Norwegian government issued amendments to “The State's
 
Guidelines for the
Remuneration of Senior Executives in Companies with State Ownership
 
(Stipulated by the Ministry of
Trade, Industry and Fisheries on 30 April 2021)” (“state guidelines”). Among other things it includes
 
an
expectation for state-owned companies in Norway such as Equinor
 
to reduce the maximum rate of
bonuses payable to leading personnel from 50% to 25%. Equinor
 
has implemented these changes in
the revised policy referred to above.
Changes in the CEC in 2022
-
 
The CEC was expanded on 1 March to formally include the position
 
of EVP Communication held
by Jannik Lindbæk (COM).
 
-
 
Aksel Stenerud joined the CEC on 1 March taking over as EVP
 
People & Organisation (PO) from
Ana Fonseca Nordang who took on another role in the company.
-
 
Geir Tungesvik joined the CEC as EVP Projects, Drilling & Procurement (PDP) on 1 May, taking
over from Arne Sigve Nylund who retired from the company on 31
 
July.
 
-
 
Hege Skryseth joined Equinor and the CEC as EVP Technology,
 
Digital & Innovation (TDI) on 1
September. She succeeded Elisabeth Birkeland Kvalheim who acted in this role after Carri
Lockhart left the CEC on 21 March and resigned from the company on
 
30 June.
 
-
 
Torgrim
 
Reitan joined the CEC on 6 October as EVP and chief financial
 
officer (CFO). He
succeeded Ulrica Fearn who stepped down from the CEC on 5 October
 
and resigned from the
company on 31 December.
-
 
Alasdair Cook resigned from the CEC on 31 December. He is succeeded by Philippe François
Mathieu.
The board believes
 
that Equinor is in a strong position to drive the execution of our
 
strategy and take on
new challenges with this strong and renewed corporate executive
 
team.
 
Jon Erik Reinhardsen
 
Chair of the board of directors
 
 
 
5
2
 
Key developments in remuneration – 2022
2.1
 
Overall company performance in 2022
 
The below summarises Equinor’s results for 2022 within the five
 
perspectives of our performance
assessment,
 
as described in the annual report.
 
Safety, security and sustainability
Strategic objective: An industry leader in safety, security and sustainability
The serious incident frequency (SIF)
 
indicator has been stable in 2022 compared to the 2021 result.
The development on the total recordable injury frequency (TRIF)
 
ratio indicator was negative compared
to 2021. The CO
2
 
intensity came in well below the target, impacted by high
 
gas production and high
regularity from low intensity fields. The scope 1 & 2 greenhouse gas
 
(GHG) net emission reduction
forecast is according to plan towards the 2030 target, but it is highly
 
affected by progress of the
abatement projects.
People and organisation
Strategic objective: A values-based and learning organisation enabled by
 
the right capabilities
 
The result on the 2022 competence indicator is positive compared
 
to 2021. There is still a gap to close
towards reaching the target within inclusion. To address the capacity gap around 2,600 new employees
have been recruited during 2022. Close follow-up of development in
 
manning level is expected going
forward. The global people survey (GPS) shows increasing scores
 
in important areas from 2021 to
2022 such as commitment, motivation and health, safety and environment
 
(HSE). There is however
remaining work and adjustments needed to achieve the effects from the new
 
operating model.
Operations
Strategic objective: A top performing energy company driving
 
the industry transformation
The total equity production of gas and liquids decreased by around
 
2% from 2,079 boe/d in 2021 to
2,039 boe/d in 2022. The total gas production increased by around
 
2.3%, whilst liquid production
decreased by around 6%. Gas production from NCS to Europe
 
increased by 8% from 2021 to 2022.
The total 2022 production is approximately on par with 2021.
The total power generation from renewables has increased by around
 
5.6% from 2021 to 2022 (from
1,562 GWh to 1,649 GWh).
Market
 
6
Strategic objective: a flexible and resilient energy portfolio
We are progressing on our energy transition plan and remain committed
 
to the ambition of net zero.
Following the Capital Market Update (CMU) responses, the performance
 
status is well received by the
investor market. Equinor’s total portfolio value has
 
grown year on year, but slightly less than target.
 
Our
oil and gas portfolio continues to be competitive, with break evens
 
for projects coming on stream the
next ten years around 35 USD/boe. We see good progress within low carbon
 
solution (LCS),
particularly with RWE, Engie partnerships and Smeaheia licence award.
 
Within renewables Equinor has an attractive development portfolio, but
 
the targeted accessed offshore
wind
 
capacity in 2022 was not achieved.
 
Finance
Strategic objective: A cash generating, profitable and competitive
 
company delivering value to our
stakeholders
 
Equinor ended on top in the peer group
1
 
ranking on return on average capital employed (RoACE) and
ended at number 6 out of 12 on the total shareholder return (TSR)
 
ranking. The financial robustness is
still strong and 2022 has shown strong earnings and cash flow from
 
operations.
 
Cost level is under pressure due to significant inflation in 2022, giving
 
reduced robustness for non-
sanctioned projects.
 
Existing contracts for our sanctioned project portfolio are less affected. Organic
capex ended below guided level in 2022.
 
The Exploration & Production Norway (EPN) portfolio has a positive trend
 
in break-even compared to
the June assessment, whilst Exploration & Production International
 
(EPI)
 
experience an increase in
break-even numbers.
2.2
 
Performance-based modifiers used in calculating variable
 
pay
As described in the remuneration policy, a threshold and a company performance modifier (“CPM”) are
applied as a means of strengthening the link between the company’s overall
 
financial results and the
individual’s variable pay. The results of these modifiers for 2022 are presented below.
 
1
The composition of Equinor’s defined peer group can be found
 
on equinor.com – link.
exhibit156p7i5
 
exhibit156p7i7 exhibit156p7i9
 
exhibit156p7i11
 
exhibit156p7i13 exhibit156p7i15 exhibit156p7i4 exhibit156p7i17
 
exhibit156p7i19
7
(1) Cash flow provided by
operating activities after tax and
before working capital items was
USD 40 billion
 
(2) Net debt ratio and
development was -24%
 
(3) Company’s overall
operational and financial
performance: ref. section 2.1.
Combined result in
«green» zone
No
reduction
in
payout
 
Equinor’s score is at
the high end
compared to peers,
resulting in a CPM at
133%
Threshold for payments under variable pay plans
With reference to the definitions and parameters described in
 
the remuneration policy, the company
performance for 2022 is assessed as being in the green zone.
Company performance modifier
With reference to the definitions and parameters described in
 
the remuneration policy, the CPM for
2022 is set at 133%.
-
 
Relative RoACE result: number 1 in the peer group of 12 companies,
 
including Equinor.
 
-
 
Relative TSR result: number 6 (second quartile) in the same peer group.
2.3
 
The board of directors’ assessment of the chief executive
 
officer’s
performance
8
Overall, 2022 was an extraordinary year also for Equinor. Impacted by the geopolitical turmoil, energy
crisis, increased focus on energy security and immediate need
 
for reliable and sanction compliant
supplies, Equinor reinforced its European energy position by
 
responding quickly to the situation.
Throughout the year, the company`s position as energy supplier to Europe was further strengthened.
Equinor's response has demonstrated the ability to accelerate the energy
 
transition in collaboration with
Norwegian government and EU, as well as through established and
 
new industry partnerships.  
 
Strong deliveries of gas supply through Europe in an extraordinarily
 
challenging context demonstrate
Equinor's high-performance operational capacity and capabilities
 
to capture high value in a volatile
market.   
 
Equinor’s strong operating results enabled conversion
 
of the high commodity prices to record results
delivering world leading pre-tax profits. The record high financial result led
 
to cash flow on par with 2021
after unprecedented tax payments and increased capital distribution.
 
Equinor’s financial position and
balance sheet has been further strengthened. Both the performance
 
and the consistency in strategy
have been well received by the investor market.    
 
The continuous drive to focus and optimise Equinor´s international
 
oil & gas business with implied risk
reduction continues according to plan, at the same time as there is
 
good progress both within
renewables and low carbon solutions.     
 
In its assessment of the chief executive officer’s performance
 
for 2022, the board of directors has
highlighted that the deliveries in key areas have been above, at or below
 
targets.  
 
The business delivery dimension for the CEO’s variable remuneration (performance
 
year 2022) was
based on an assessment against the following KPIs: SIF, Upstream CO2 intensity, Capex share
REN/LCS, relative TSR, relative ROACE. Ref. also Table 4 for details.   
 
The 12 months SIF ratio result of 0.4 is according to target, and a historical
 
low. Over the last 12
months we have seen a decrease in incidents compared to 2021 numbers
 
although the activity level in
2022 was higher than the 2021 level (~5% more hours).  
 
The CO2 intensity ended at 6.9 kg CO2/boe, well below target of 8
 
kg CO2/boe and slightly lower than
2021. Emission reduction initiatives as well as high gas production
 
and high regularity from low intensity
fields are main contributors. Lower than normal production from
 
Peregrino and Snøhvit contributed to
the reduced CO2 intensity. 
 
The Capex share to Renewable/Low Carbon Solutions result ended
 
at 14 % compared to a target of
>15%. This is an increase from 11% last year. Although a modest result measured purely against
target, the board appreciates the capital discipline demonstrated
 
by avoiding bidding on excessively
priced renewables license rounds, irrespective of KPI target.   
 
Equinor’s return on RoACE was best in the peer
 
group. Relative position in the peer group for TSR was
number 6, which is above average (target level).  
 
Implementation of the new operating model (One Equinor 2021)
 
is progressing, but there is still
identified improvement potential and related actions to be accomplished.   
 
Employee surveys show progress in many key areas from 2021
 
to 2022. Areas like safety, conduct,
trust in leadership and company strategic ambitions score high across
 
the business. The need to
maintain focus on continuous improvement in some areas has also been
 
identified. The board's
impression of progress and status on overall employee satisfaction
 
is positive.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
9
2.4
 
Summary of targets and achievement of corporate KPIs and
 
goals forming
the basis for annual variable pay
The board of directors decides on a comprehensive set of KPIs
 
and behaviour goals to facilitate
direction and areas of focus prior to each calendar year. The KPIs and behaviour goals to be used by
the board of directors to assess the CEO’s performance in relation to the
 
AVP for the upcoming
calendar year are selected from this set and included in an annual
 
performance contract with the CEO.
The selected KPIs and goals are those assessed to be most critical in achieving
 
the core strategic
objectives for the company in the coming year.
 
The corporate delivery KPIs and behaviour goals selected for the
 
CEO are similarly set forth in a
performance contract between the CEO and EVPs, to the extent
 
these are deemed relevant. For the
EVPs of business areas, a selection of additional business area KPIs
 
supporting the company’s
strategic ambitions from the specific business area is included in their performance
 
contracts.
 
From performance to AVP
 
award
As described in the remuneration policy, performance forms the basis for the decision on annual
variable pay (“AVP”) percentages for the members of the CEC.
Common corporate delivery KPIs, business area specific delivery KPIs and
 
behaviour goals are
measured separately and assessed holistically, as described below.
These together form the basis for payment of annual variable pay, where delivery KPIs and behaviour
goals each have a weight of 50%. For EVPs in business areas delivery
 
KPIs are weighted to comprise
50% corporate KPIs and 50% business area specific KPIs.
 
The individual KPIs and goals within a category are equally weighted
 
initially and can be adjusted to
reflect prevailing business context and strategic priorities.
 
Group of CEC member
 
Weighting of KPIs in “what”
 
dimension – 50%
 
Weighting of goals
in “how”
dimension
 
– 50%
Corporate
delivery KPIs
Business area
delivery KPIs
Corporate
behaviour goals
CEO and staffs EVPs
50%
-
50%
EVPs with BA responsibility
25%
25%
50%
Delivery in 2022 against the selected corporate delivery goals (“what” dimension)
 
which are applied to
the CEO, as well as the individual EVPs, is summarized as follows:
 
 
 
 
 
 
 
 
10
KPI
 
Target
 
Performance
 
• Serious Incident Frequency
 
0.4 or better
 
0.4
• CO
2
 
intensity for the upstream portfolio
8 kg CO
2
 
per boe or better
6.9
• Relative Total Shareholder Return
Ranked better than peer average
 
6 of 12
• Relative RoACE
 
Ranked in first quartile among peers
1 of 12
• Gross capex share of renewable and low carbon
 
solutions
> 15%
14 %
 
In terms of the “how” dimension, common behaviour goals are defined
 
for the CEO and the EVPs with
reference to Equinor’s core values and leadership
 
principles,
 
as follows:
-
 
Demonstrate accountability, visibility,
 
and engagement for safety and compliance
-
 
Build trust in the CEC and Equinor
-
 
Transform own organisation to deliver on our common purpose and become a leading company
in the energy transition
-
 
Develop strong succession pipeline
Performance against these behaviour goals is measured on an individual
 
basis for the CEC members.
The KPI targets and results of the business deliveries (“what”),
 
and the behaviour goals and results
(“how”) and how these translate into the AVP award are presented for the individual CEC members in
the Table
 
4 section further below.
 
The KPI targets and behaviour goals applicable for the performance
 
measurement for
AV
P in 2023 are
presented in section 4.5.
2.5
 
Key developments in corporate executive remuneration
 
in 2022
Execution of policy on executive remuneration in 2022
The remuneration of the CEC members for 2022 was determined
 
in accordance with the remuneration
policy and principles approved by the AGM on 11 May 2021. These principles, as well as details on the
elements constituting executive remuneration are outlined in Equinor’s
 
remuneration policy, see
Appendix.
The values-based performance framework and the main elements of remuneration
 
applies
 
to the CEC
members employed by Equinor ASA and subsidiaries,
 
in accordance with Equinor’s remuneration
policy.
 
For 2022 Alasdair Cook and Carri Lockhart held positions with the CEC.
 
Their terms and conditions
were in accordance with local market practice in their respective base
 
countries and Equinor’s
applicable remuneration policies, ref. below.
Remuneration policy changes
11
As noted in the 2021 annual report, the following changes were
 
introduced to the remuneration policy
effective 2022, in accordance with the updated requirements of the state:
-
 
the maximum AVP potential has been reduced to 45% from 50% of base salary
-
 
the share savings plan has been defined as variable pay under
 
the guidelines, and thereby falls
under the 80% maximum variable pay
-
 
the holding period for shares under the employee share savings plan
 
has been increased from two
to three calendar years for the CEC members.
General notes on remuneration elements
Fixed pay
The annual salary increases for the members of the CEC in
 
2022 were in line with the general salary
increase frame in the relevant Equinor entity.
 
Variable pay
Based on the overall company performance in 2022
 
and in accordance with the threshold criteria
described in the remuneration policy the AVP payments were not reduced.
 
The target for annual variable pay for members of the CEC employed
 
by Equinor ASA was 25% of base
salary, and the maximum annual variable pay for 2022 was 45% of base salary. For members of the
CEC employed outside the Norwegian market other targets and
 
maximum limit for annual variable pay
apply.
 
The company performance modifier and the threshold affect the final annual
 
variable pay award. As
described above, the CPM was set at 133% for 2022.
 
There was no threshold effect applied for 2022.
The LTI grants in 2022 were not reduced, as the threshold for the previous year – 2021 – was in the
“green” zone.
Benefits
 
As described in the remuneration policy, members of the CEC employed in Equinor ASA are covered
by the company’s general occupational defined contribution pension scheme.
 
A defined benefit scheme
is retained for a grandfathered group of employees. In 2022, this applies
 
to Arne Sigve Nylund and Geir
Tungesvik.
 
A fixed salary addition calculated as 18% of base salary is provided in lieu
 
of pension accrual above 12
G to members of the CEC covered by the general defined contribution
 
pension scheme and
who were
employed by Equinor ASA before 1 September 2017. This addition
 
does not form part either of the
pensionable salary or of the basis for variable pay.
Members of the CEC employed in other subsidiaries have different pension
 
arrangements, as
described below.
Notes on roles and remuneration of CEC members in 2022
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
12
CEC member
Position
Period on CEC in 2022 and notes on
remuneration
Anders Opedal
 
President and chief
executive officer (CEO)
Full year
Irene Rummelhoff
 
EVP Marketing, Midstream
& Processing (MMP)
Full year
Arne Sigve Nylund
 
EVP Projects, Drilling &
 
Until 30 April
Geir Tungesvik
Procurement (PDP)
As of 1 May
Jannicke Nilsson
 
EVP Safety, Security &
Sustainability (SSU)
Full year
Pål Eitrheim
 
EVP Renewables (REN)
Full year
Alasdair Cook
EVP Exploration &
Production International
(EPI)
Full year.
Employed in Equinor UK Ltd. Terms decided
as appropriate due to local market conditions.
-
 
AVP target level at 40% of base salary
(maximum 80%)
 
-
 
Long term incentive grant of 70% of base
salary
-
 
Cash compensation in lieu of pension
accrual.
Kjetil Hove
 
EVP Exploration &
Production Norway (EPN)
Full year
Carri Lockhart
EVP Technology,
 
Digital &
Innovation (TDI)
Until 21 March.
Was employed by Equinor US Operations
LLC; resigned on 30 June.
 
Terms
 
decided as
appropriate due to local market conditions.
-
 
AVP target 50% of base salary (max
100%)
 
-
 
Long term incentive grant of 70% of base
salary
-
 
Carri Lockhart participates in a
supplementary defined contribution
pension scheme – SERP.
 
This was
established with her former employer and
continued in Equinor US Operations LLC
when she joined in 2016.
 
Elisabeth Birkeland
Kvalheim
Acting EVP from 22 March to 31 August
Hege Skryseth
From 1 September
Ulrica Fearn
EVP and Chief financial
officer (CFO)
Until 5 October;
 
resigned 31 December
Recruited from UK; remuneration until 15 June
was agreed to be equal to being on
international assignment from UK to Norway.
As of 16 June additional benefits were
provided with respect to housing and
schooling.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
13
CEC member
Position
Period on CEC in 2022 and notes on
remuneration
Torgrim
 
Reitan
From 6 October.
Torgrim
 
Reitan is entitled to early retirement
from age 65 with a pension level amounting to
66% of pensionable salary.
Siv Helen Rygh
Torstensen
 
EVP Legal & Compliance
(LEG)
Full year
Ana Fonseca
Nordang
EVP People & Organisation
(PO)
Until 28 February
Aksel Stenerud
From 1 March
Jannik Lindbæk
EVP Communication (COM)
From 1 March
2.6
 
Derogations and deviations from remuneration policy
 
There were no derogations from the remuneration policy in 2022.
2.7
 
Right to reclaim (‘malus and clawback’)
There were no cases where the right to reclaim was exercised in 2022.
2.8
 
Shareholder feedback on the remuneration report for 2021
The remuneration report for 2021 was presented for approval (advisory
 
vote) at the annual general
meeting on 11 May 2022 and was endorsed by a significant majority. 98.96% of the votes cast were in
favour of the remuneration report for 2021. MTIF issued a statement
 
to the 2022 AGM,
 
as included in
section 1.2.
2.9
 
Activities of the compensation and executive development committee
 
in 2022
The activities of the BCC in 2022 were in line with the instructions from
 
the board of directors which are
available on equinor.com.
 
The BCC had a high focus in 2022 on addressing the comments
 
from the MTIF provided at the 2022
AGM. This included discussing and reviewing proposals for:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
14
-
 
adopting a more consistent approach and detailed template
 
for performance contracts
 
containing
KPIs and goals used as a basis for setting AVP awards, applicable both to the CEO and the EVPs
effective 2022
-
 
a revised remuneration policy and remuneration report, presenting
 
the information in a more
structured and concise way,
 
and with increased transparency on Equinor’s
 
approach to pay-for-
performance and paying due regard to the principle of moderation.
Other activities included:
-
 
Discussions on the trends within the executive talent market and executive
 
remuneration
-
 
Executive succession planning and talent review
-
 
Recommendation to the board on the threshold used in calculating variable
 
remuneration, based
on relevant company performance results
-
 
Recommendation to the board on the base salary review for the
 
CEO
-
 
Review and submission for approval of the board of the performance evaluation
 
and goals for the
CEO
 
-
 
Assessment and submission for the decision of the board of the proposal
 
for AVP of the CEO
-
 
Presentation by the CEO of the performance assessment and
 
considerations on AVP awards to
the EVPs
-
 
Discussion of the evaluation by the board and self-assessment of
 
the performance of the BCC
-
 
Review and submission for approval of the board of the instructions
 
to the BCC
3
 
Remuneration and share ownership of the board of directors and
corporate assembly
3.1
 
Remuneration of the board of directors
 
In 2022, the total remuneration to the board, including fees for
 
the board's three committees, was USD
801 thousand (NOK 7,662
 
thousand).
 
Detailed information about the individual remuneration to the
 
members of the board of directors in 2022
is provided in the table below.
Total remuneration
Members of the board (figures in USD thousand)
2018
2019
2020
2021
2022
Jon Erik Reinhardsen (chair of the board)
117
110
108
119
110
Jeroen van der Veer (deputy chair of the board)
1
95
101
96
98
52
Anne Drinkwater (deputy chair of the board)
2
48
100
88
82
96
Bjørn Tore Godal
3
70
67
64
70
62
Rebekka Glasser Herlofsen
66
62
59
66
66
Jonathan Lewis
 
44
93
76
70
80
Finn Bjørn Ruyter
 
-
37
69
77
71
Tove Andersen
 
-
-
27
59
55
Michael Lewis
4
28
Haakon Bruun-Hanssen
5
-
Per Martin Labråten
6
59
56
54
66
65
Stig Lægreid
6
59
56
54
59
55
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
15
Hilde Møllerstad
6
-
32
59
66
61
Employee elected deputy members of the board
Hans Einar Haldorsen
-
-
-
-
Bjørn Palerud
-
-
-
-
Anita Skaga Myking
-
-
-
-
Total remuneration
558
714
754
832
801
1)
 
Member of the board until 30 June 2022
2)
 
Deputy chair of the board from 1 July 2022
3)
 
Member of the board until 11 December 2022
4)
 
Member of the board from 1 July 2022
5)
 
Member of the board from 12 December 2022
6)
 
Employee-elected members of the board
3.2
 
Total
 
number and value of shares held by the members
 
of the board of
directors
The number of Equinor shares owned by members of the board of and/or
 
owned by their close
associates is shown below. Individually, each member of the board of directors owned less than 1% of
the outstanding Equinor shares.
The voting rights of members of the board of directors, the CEC and
 
the corporate assembly as a
shareholder do not differ from those of ordinary shareholders.
Ownership of Equinor
shares (incl. shares owned
by close associates)
As of 1
Jan.
2022
As of 31
Dec. 2022
Market
value as of
31 Dec.
2022, USD
thousand
As of 14
March 2023
Jon Erik Reinhardsen
4,584
4,584
168
4,584
Jeroen van der Veer
6000
-
 
-
-
Anne Drinkwater
1,100
1,100
40
1,100
Bjørn Tore
 
Godal
-
-
 
-
-
Rebekka Glasser Herlofsen
220
220
8
220
Jonathan Lewis
-
-
 
-
-
Finn Bjørn Ruyter
620
620
23
620
Tove
 
Andersen
4,700
4,700
172
4,700
Michael Lewis
-
-
-
-
Haakon Bruun-Hanssen
-
-
-
-
Per Martin Labråten
2,642
587
22
796
Stig Lægreid
125
5
0
5
Hilde Møllerstad
5,234
6,290
231
7,185
Deputy members
 
-
-
 
-
-
Hans Einar Haldorsen
2,961
1,875
69
2,574
Bjørn Palerud
4,680
974
36
1,217
Anita Skaga Myking
5,898
6,240
229
6,544
3.3
 
Remuneration of the corporate assembly
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
16
In 2022, the total remuneration to the shareholder and employee-elected
 
members of the corporate
assembly was USD 135 thousand (NOK 1,296 thousand).
Total remuneration
Corporate assembly employee elected members (figures in
 
USD thousand)
2021
2022
 
Berit Søgnen Sandven
6
5
Frode Mikkelsen
6
5
Lars Olav Grøvik
6
5
Oddvar Karlsen
6
5
Peter Bernhard Sabel
6
5
Terje
 
S. Enes
6
5
Per Helge Ødegård (observer)
6
5
Ingvild Berg Martiniussen (observer)
6
5
Anne Kristi Horneland (observer)
6
5
Employee elected deputy members who received member
 
fees
Terje
 
Herland
1
1
Steinar Kåre Dale
1
2
Vidar Frøseth
-
1
Kjetil Gjerstad
-
2
Frank Indreland Gundersen
-
1
Katrine Knarvik-Skogstø
-
2
Total
 
remuneration
56
 
54
 
3.4
 
Shares held by the members of the corporate assembly
Individually, each member of the corporate assembly owned less than 1% of the outstanding Equinor
shares as of 31 December 2022 and as of 14 March 2023. In aggregate,
 
members of the corporate
assembly owned a total of 27,155 shares as of 31 December 2022
 
and a total of 28,762 shares as of
14 March 2023. Information about the individual share ownership of
 
the members of the corporate
assembly is presented in the section 5.8 of the annual report «Corporate
 
assembly, board of directors
and management”.
 
4
 
Remuneration and share ownership of the CEC
4.1
 
Remuneration of the CEC
In 2022, the aggregate remuneration to the CEC was USD 12,647 thousand
 
(2021: USD 11,936
thousand).
 
No loans have been granted by the company to members of
 
the CEC.
Below is an overview of the total remuneration of the CEC members
 
in 2022.
 
exhibit156p17i0 exhibit156p17i1
17
Table
 
1 – Remuneration of the corporate executive committee for the reported
 
financial year
2022
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
18
Fixed remuneration
Variable remuneration
Fees
One-
year
variable
Multi-year
variable
Members of the corporate
 
executive committee
 
(figures in USD thousand)
Base
salary
Fixed
salary
addition
Other
fees
Fringe
benefits
AVP
LTI
SSP
Extra-
ordinary
items
Pension
expenses
Total
remune-
ration
Proportion of
fixed and
variable
remuneration
Anders Opedal
999
180
97
28
411
295
6
0
28
2042
63%/37%
Irene Rummelhoff
436
78
74
10
198
107
28
0
29
961
63%/37%
Jannicke Nilsson
360
65
87
47
138
89
23
0
37
844
68%/32%
Pål Eitrheim
393
71
31
23
146
97
0
0
23
783
67%/33%
Kjetil Hove
490
88
72
31
202
120
21
0
30
1055
65%/35%
Siv Helen Rygh Torstensen
311
56
68
20
120
77
14
0
27
691
68%/32%
Arne Sigve Nylund
151
0
13
8
37
29
79
0
48
365
59%/41%
Geir Tungesvik
264
48
37
1
98
65
12
0
17
541
65%/35%
Ulrica Fearn
479
0
298
43
0
 
0
0
0
14
833
100%/0%
Torgrim Reitan
116
20
21
1
46
36
0
0
6
245
64%/36%
Ana Fonseca Nordang
53
10
10
2
18
13
2
0
3
110
69%/31%
Aksel Stenerud
260
47
49
17
101
64
10
0
28
575
67%/33%
Elisabeth Birkeland
Kvalheim
130
20
14
1
43
22
7
0
14
251
69%/31%
Hege Skryseth
139
0
33
1
52
35
0
156
6
422
41%/59%
Jannik Lindbæk
257
46
24
17
99
63
14
0
26
546
65%/35%
Alasdair Cook
714
0
412
75
0
443
0
0
0
1643
73%/27%
Carri Lockhart
110
87
332
27
0
153
12
0
18
738
78%/22%
2021
Fixed remuneration
Variable remuneration
Fees
One-
year
variable
Multi-year
variable
Members of the corporate
 
executive committee
 
(figures in USD thousand)
Base
salary
Fixed
salary
addition
Other
fees
Fringe
benefits
AVP
LTI
SSP
Extra-
ordinary
items
Pension
expenses
Total
remune-
ration
Proportion of
fixed and
variable
remuneration
 
 
 
19
Anders Opedal
1,071
193
84
22
493
159
4
0
30
2,055
68% / 32%
Irene Rummelhoff
469
85
55
10
201
58
14
0
31
924
70% / 30%
Jannicke Nilsson
388
70
69
42
160
48
14
0
39
830
73% / 27%
Pål Eitrheim
400
72
33
19
200
46
0
0
25
796
69% / 31%
Kjetil Hove
478
86
60
35
258
43
13
0
32
1,004
69% / 31%
Siv Helen Rygh Torstensen
197
35
22
1
81
20
5
0
17
378
72% / 28%
Arne Sigve Nylund
496
0
45
33
212
61
0
0
152
1,000
73% / 27%
Ulrica Fearn
367
0
299
106
163
48
0
0
11
993
79% / 21%
Ana Fonseca Nordang
204
37
26
5
84
18
4
0
14
393
73% / 27%
Alasdair Cook
765
0
163
60
564
347
13
0
0
1,912
52% / 48%
Carri Lockhart
307
112
216
70
227
199
8
0
46
1,184
63% / 37%
Notes to the table “Remuneration of the corporate executive committee
 
for the reported financial year”:
●
 
The figures are presented on an accrual basis, i.e. for the earning period.
 
●
 
For executives who were a member of the CEC for only part of 2022, all
 
compensation and benefits
have been allocated accordingly. See table in section “Notes on remuneration of CEC members in
2022” for details on position changes.
●
 
Comparative figures are included for those employees who were part
 
of the CEC in both 2022 and
2021.
●
 
All CEC members received
 
their remuneration in NOK except Alasdair Cook who received
 
the
remuneration in GBP,
 
and Carri Lockhart who received
 
remuneration in USD.
●
 
All figures in the table are presented in USD based on average
 
foreign currency exchange rates.
Average rates 2022: NOK/USD = 0.1043,
 
GBP/USD = 1.2355,
 
(2021: NOK/USD = 0,1164,
GBP/USD = 1,3756).
 
●
Fixed salary addition
: for Carri Lockhart the amount represents company contributions
 
to the
SERP plan.
●
Other fees
 
include car allowance, holiday pay and other cash payments.
 
For Ulrica Fearn this
category includes the agreed remuneration referred to in the section “Notes
 
on roles and
remuneration of CEC members in 2022”. For Alasdair Cook and Carri
 
Lockhart the category
includes
 
compensation according to Equinor’s international
 
assignment terms. Additionally for
Alasdair Cook this category includes
 
USD 107
 
thousand in lieu of pension contributions
 
for 2022.
●
Fringe benefits
 
include benefits in kind such as company car, commuter apartments, health
program.
 
●
AVP
(annual variable pay) includes holiday pay on the AVP payment for CEC members employed
in Equinor ASA and
resident in Norway.
●
LTI
(long-term incentive)
:
With reference to the remuneration policy, the LTI plan is share-based in
Equinor ASA and cash-based in the international subsidiaries. For CEC
 
members employed in
Equinor ASA the value included in Table 1 represents the grant,
 
i.e. gross amount, which, after
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
20
deduction of tax is invested in shares in the reporting year and subject
 
to a lock-in period. For CEC
members employed in the international subsidiaries this represents
 
the pay-out under the cash-
based plan after the lock-in period. Refer to the remuneration policy
 
for further details.
 
●
SSP
(share savings plan):
the amounts represent the value of the bonus shares received in
 
the
reporting year after the applicable holding period. For Arne Sigve Nylund
 
it also includes the shares
awarded at retirement. Refer to the remuneration policy for details of
 
this plan.
 
●
Extraordinary items:
For Hege Skryseth this represents a sign-on bonus.
●
Pension expenses:
Estimated pension cost for the defined benefit scheme is
 
calculated based on
actuarial assumptions and pensionable salary (mainly base salary)
 
at 31 December 2021 and is
recognised as pension cost in the statement of income for 2022. Arne Sigve
 
Nylund
 
and Geir
Tungesvik are maintained in the closed defined benefit scheme.
 
The pension cost for the defined
contribution scheme is represented by the respective contributions. For
 
the notional contribution
scheme, the pension cost is represented by the contributions and
 
the fair value changes of the
employees’ notional assets. The remaining members of the CEC employed
 
by Equinor ASA are
covered by the defined contribution pension scheme. For Carri Lockhart,
 
refer to comment under
“Fixed salary addition” above.
 
For Alasdair Cook, refer to comment under “Other fees” above.
4.2
 
Shares awarded or due to the CEC
for the reported financial year
 
Table
 
3
 
Refer to the remuneration policy for details of the share-based plans.
-
 
For those CEC members who were on the CEC less than a full year
 
in 2022 the number of shares
refers to the CEC period.
-
 
Column 4 “Vesting date” has been excluded from the table, as this represents the same date as
shown in column 5 “End of holding period”.
-
Column 9 “Shares subject to a performance condition” has
 
been excluded from the table, as there
are no performance conditions in relation to shares.
-
Column 10 “Shares awarded and unvested at year end” has been excluded
 
from the table, as this
represents the same date as shown in column 11 “Shares subject to a holding period“
-
 
Name,
Position
The main conditions of share award plans
Information regarding the reported financial year
 
 
 
 
Opening
 
balance
During the year
Closing
balance
1
 
Specifi-
cation
of plan
2
 
Perfor-
mance
period
 
3
Award date
5
 
End of
holding
period
6
 
Shares
awarded at
the
beginning
of the year
7
 
Shares
awarded
8
 
Shares vested
11
 
Shares
subject to a
holding
period
 
LTI
2019 - 2021
05/08/2019
05/07/2022
2,997
 
2,997
 
 
 
 
 
 
 
USD 105,414
 
 
2020 - 2022
05/29/2020
05/28/2023
3,830
 
 
3,830
 
2021 - 2023
06/17/2021
06/16/2024
3,614
 
 
3,614
Anders Opedal
2022 - 2024
05/20/2022
05/19/2025
 
4,002
 
4,002
CEO
 
 
 
 
USD 138,531
 
 
 
SSP
2022
01/18/2022
 
 
212
 
 
 
 
 
 
 
USD 5,633
 
 
 
SUM
 
 
 
10,441
4,214
2,997
11,446
 
 
 
 
 
USD 144,163
USD 105,414
 
The main conditions of share award plans
Information regarding the reported financial year
 
 
 
 
Opening
balance
During the year
Closing
balance
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
21
Name,
Position
1
 
Specif
i-
cation
of
plan
2
 
Perfor-
mance
period
 
3
Award date
5
 
End of
holding
period
6
 
Shares
awarded at
the
beginning
of the year
7
 
Shares
awarded
8
 
Shares vested
11
 
Shares
subject to a
holding
period
 
LTI
2019 - 2021
05/08/2019
05/07/2022
2,858
 
2,858
 
 
 
 
 
 
USD 100,525
 
2020 - 2022
05/29/2020
05/28/2023
3,802
 
 
3,802
 
2021 - 2023
06/17/2021
06/16/2024
1,267
 
 
1,267
Irene Rummelhoff
2022 - 2024
05/20/2022
05/19/2025
 
1,487
 
1,487
EVP MMP
 
 
 
 
USD 51,473
 
 
 
SSP
2022
01/18/2022
 
 
1,040
 
 
 
 
 
 
 
USD 27,633
 
 
 
SUM
 
 
 
7,927
2,527
2,858
6,556
 
 
 
 
 
USD 79,106
USD 100,525
 
Name,
Position
The main conditions of share award plans
Information regarding the reported financial year
 
 
 
 
Opening
balance
During the year
Closing balance
1
 
Specifi-
cation
of plan
2
 
Perfor-
mance
period
 
3
Award date
5
 
End of
holding
period
6
 
Shares
awarded at
the
beginning
of the year
7
 
Shares
awarded
8
 
Shares vested
11
 
Shares
subject to a
holding
period
 
LTI
2019 - 2021
05/08/2019
05/07/2022
2,365
 
2,365
 
 
 
 
 
 
 
USD 83,185
 
 
2020 - 2022
05/29/2020
07/31/2022
4,036
 
4 036
 
 
 
 
 
 
 
USD 155,370
 
Arne Sigve Nylund
2021 - 2023
06/17/2021
07/31/2022
1,339
 
1 339
 
EVP PDP
 
 
 
 
 
 
USD 51,546
 
 
2022 - 2024
05/20/2022
07/31/2022
 
528
528
 
 
 
 
 
 
USD 18,261
USD 20,326
 
 
SSP
2022
01/18/2022
 
 
619
 
 
 
 
 
 
 
USD 16,453
 
 
 
2022
06/16/2022
 
 
1,683
 
 
 
 
 
 
 
USD 61,483
 
 
 
SUM
 
 
 
7,740
2,830
8,268
 
 
 
 
 
 
USD 96,197
USD 310,426
 
-
 
The end of holding period under the LTI plan dated 31 July 2022 is due to retirement on 31 July
2022.
-
 
Allocation of bonus shares under the SSP on 16 June 2022 is
 
due to retirement.
Name,
Position
The main conditions of share award plans
Information regarding the reported financial year
 
 
 
 
Opening
balance
During the year
Closing balance
1
 
Specifi-
cation
of plan
2
 
Perfor-
mance
period
 
3
Award date
5
 
End of
holding
period
6
 
Shares
awarded at
the
beginning
of the year
7
 
Shares
awarded
8
 
Shares vested
11
 
Shares
subject to a
holding
period
 
LTI
2022 - 2024
05/20/2022
05/19/2025
 
863
 
863
 
 
 
 
 
USD 29,869
 
 
Geir Tungesvik
SSP
2022
01/18/2022
 
 
443
 
 
EVP PDP
 
 
 
 
USD 11,771
 
 
SUM
 
 
 
 
1,306
 
863
 
 
 
 
 
USD 41,640
 
 
The main conditions of share award plans
Information regarding the reported financial year
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
22
Name,
Position
 
 
 
 
Opening
balance
During the year
Closing balance
1
 
Specifi-
cation
of plan
2
 
Perfor-
mance
period
 
3
Award date
5
 
End of
holding
period
6
 
Shares
awarded at
the
beginning
of the year
7
 
Shares
awarded
8
 
Shares vested
11
 
Shares
subject to a
holding
period
 
LTI
2019 - 2021
05/08/2019
05/07/2022
2,365
 
2,365
 
 
 
 
 
 
 
USD 83,185
 
 
2020 - 2022
05/29/2020
05/28/2023
3,205
 
 
3,205
 
2021 - 2023
06/17/2021
06/16/2024
1,091
 
 
1,091
Jannicke Nilsson
2022 - 2024
05/20/2022
05/19/2025
 
1,254
 
1,254
EVP SSU
 
 
 
 
USD 43,408
 
 
 
SSP
2022
01/18/2022
 
 
862
 
 
 
 
 
 
 
USD 22,903
 
 
 
SUM
 
 
 
6,661
2,116
2,365
5,550
 
 
 
 
 
USD 66,311
USD 83,185
 
Name,
Position
The main conditions of share award plans
Information regarding the reported financial year
 
 
 
 
Opening
balance
During the year
Closing
balance
1
 
Specifi
-cation
of plan
2
 
Perfor-
mance
period
 
3
Award date
5
 
End of
holding
period
6
 
Shares
awarded at
the
beginning
of the year
7
 
Shares
awarded
8
 
Shares vested
11
 
Shares
subject to a
holding
period
 
LTI
2019 - 2021
05/08/2019
05/07/2022
2,503
 
2,503
 
 
 
 
 
 
 
USD 88,039
 
 
2020 - 2022
05/29/2020
05/28/2023
3,385
 
 
3,385
 
2021 - 2023
06/17/2021
06/16/2024
1,153
 
 
1,153
Pål Eitrheim
2022 - 2024
05/20/2022
05/19/2025
 
1,478
 
1,478
EVP REN
 
 
 
 
USD 51,161
 
 
 
SUM
 
 
 
7,041
1,478
2,503
6,016
 
 
 
 
 
USD 51,161
USD 88,039
 
Name,
Position
The main conditions of share award plans
Information regarding the reported financial year
 
 
 
 
Opening
balance
During the year
Closing
balance
1
 
Specifi
-cation
of plan
2
 
Perfor-
mance
period
 
3
Award date
5
 
End of
holding
period
6
 
Shares
awarded at
the
beginning
of the year
7
 
Shares
awarded
8
 
Shares vested
11
 
Shares
subject to a
holding
period
 
LTI
2021 - 2023
06/17/2021
06/16/2024
997
 
 
997
 
2022 - 2024
05/20/2022
05/19/2025
 
1,670
 
1,670
Kjetil Hove
 
 
 
 
USD 57,808
 
 
EVP DPN/EPN
SSP
2022
01/18/2022
 
 
800
 
 
 
 
 
 
 
USD 21,256
 
 
 
SUM
 
 
 
997
2,470
 
2,667
 
 
 
 
 
USD 79,064
 
 
Name,
Position
The main conditions of share award plans
Information regarding the reported financial year
 
 
 
 
Opening
balance
During the year
Closing balance
1
 
Specifi-
cation
of plan
2
 
Perfor-
mance
period
 
3
Award date
5
 
End of
holding
period
6
 
Shares
awarded at
the
beginning
of the year
7
 
Shares
awarded
8
 
Shares vested
11
 
Shares
subject to a
holding
period
 
LTI
2022 - 2024
05/20/2022
05/19/2025
 
320
 
320
 
 
 
 
 
USD 11,084
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
23
Elisabeth B Kvalheim
SSP
2022
01/18/2022
 
 
270
 
 
EVP TDI
 
 
 
 
 
USD 7,179
 
 
 
SUM
 
 
 
 
590
 
320
 
 
 
 
 
USD 18,262
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
24
Name,
Position
The main conditions of share award plans
Information regarding the reported financial year
 
 
 
 
Opening
balance
During the year
Closing
balance
1
 
Specifi
-cation
of plan
2
 
Perfor-
mance
period
 
3
Award date
5
 
End of
holding
period
6
 
Shares
awarded at
the
beginning
of the year
7
 
Shares
awarded
8
 
Shares vested
11
 
Shares
subject to a
holding
period
 
LTI
2022 - 2024
11/18/2022
11/17/2025
 
461
 
461
Hege Skryseth
 
 
 
 
USD 17,064
 
 
EVP TDI
SUM
 
 
 
 
461
 
461
 
 
 
 
 
USD 17,064
 
 
Name,
Position
The main conditions of share award plans
Information regarding the reported financial year
 
 
 
 
Opening
balance
During the year
Closing
balance
1
 
Specifi-
cation
of plan
2
 
Perfor-
mance
period
 
3
Award date
5
 
End of
holding
period
6
 
Shares
awarded at
the
beginning
of the year
7
 
Shares
awarded
8
 
Shares vested
11
 
Shares
subject to a
holding
period
 
LTI
2021 - 2023
 
03/24/2022
12/31/2022
 
795
795
 
 
 
 
 
 
USD 23,491
USD 29,178
 
Ulrica Fearn
2022 - 2024
05/20/2022
12/31/2022
 
1,825
1,825
 
EVP CFO
 
 
 
 
USD 63,169
USD 66,980
 
SUM
 
 
 
 
2,620
2,620
 
 
 
 
 
USD 86,661
USD 96,158
 
-
 
The end of holding period dated 31 December 2022 is due
 
to termination of employment on 31
December 2022.
-
 
The 2021-2023 grant was included in Table 1 in chapter 3.12 of the 2021 annual report. The
related shares were allocated in 2022.
Name,
Position
The main conditions of share award plans
Information regarding the reported financial year
 
 
 
 
Opening
balance
During the year
Closing balance
1
 
Specifi-
cation
of plan
2
 
Perfor-
mance
period
 
3
Award date
5
 
End of
holding
period
6
 
Shares
awarded at
the
beginning
of the year
7
 
Shares
awarded
8
 
Shares vested
11
 
Shares
subject to a
holding
period
 
LTI
2019 - 2021
05/08/2019
05/07/2022
2,539
 
2,539
 
 
 
 
 
 
 
USD 89,305
 
 
2020 - 2022
05/29/2020
05/28/2023
3,376
 
 
3,376
Torgrim Reitan
2022 - 2024
05/20/2022
05/19/2025
 
283
 
283
EVP CFO
 
 
 
 
USD 9,810
 
 
 
 
11/18/2022
11/17/2025
 
117
 
117
 
 
 
 
 
USD 4,331
 
 
SSP
2022
01/18/2022
 
 
255
 
 
 
 
 
 
USD 6,770
 
 
SUM
 
 
 
5,915
655
2,539
3,776
 
 
 
 
USD 20,911
USD 89,305
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
25
Name,
Position
The main conditions of share award plans
Information regarding the reported financial year
 
 
 
 
Opening
balance
During the year
Closing
balance
1
 
Specifi
-cation
of plan
2
 
Perfor-
mance
period
 
3
Award date
5
 
End of
holding
period
6
 
Shares
awarded at
the
beginning
of the year
7
 
Shares
awarded
8
 
Shares vested
11
 
Shares
subject to a
holding
period
 
LTI
2021 - 2023
06/17/2021
06/16/2024
545
 
 
545
 
2022 - 2024
05/20/2022
05/19/2025
 
1,172
 
1,172
Siv H Rygh Torstensen
 
 
 
 
USD 40,569
 
 
EVP LEG
SSP
2022
01/18/2022
 
 
510
 
 
 
 
 
 
 
USD 13,551
 
 
 
SUM
 
 
 
545
1,682
 
1,717
 
 
 
 
 
USD 54,120
 
 
Name,
Position
The main conditions of share award plans
Information regarding the reported financial year
 
 
 
 
Opening
balance
During the year
Closing
balance
1
 
Specifi-
cation
of plan
2
 
Perfor-
mance
period
 
3
Award date
5
 
End of
holding
period
6
 
Shares
awarded at
the
beginning
of the year
7
 
Shares
awarded
8
 
Shares vested
11
 
Shares
subject to a
holding
period
 
LTI
2021 - 2023
06/17/2021
06/16/2024
502
 
 
502
 
2022 - 2024
05/20/2022
05/19/2025
 
197
 
197
Ana Fonseca Nordang
 
 
 
 
USD 6,815
 
 
EVP PO
SSP
2022
01/18/2022
 
 
72
 
 
 
 
 
 
 
USD 1,903
 
 
 
SUM
 
 
 
502
268
 
699
 
 
 
 
 
USD 8,718
 
 
Name,
Position
The main conditions of share award plans
Information regarding the reported financial year
 
 
 
 
Opening
balance
During the year
Closing
balance
1
 
Specifi-
cation
of plan
2
 
Perfor-
mance
period
 
3
Award date
5
 
End of
holding
period
6
 
Shares
awarded at
the
beginning
of the year
7
 
Shares
awarded
8
 
Shares vested
11
 
Shares
subject to a
holding
period
 
LTI
2022 - 2024
05/20/2022
05/19/2025
 
922
 
922
 
 
 
 
 
USD 31,909
 
 
Aksel Stenerud
SSP
2022
01/18/2022
 
 
376
 
 
EVP PO
 
 
 
 
USD 10,002
 
 
 
SUM
 
 
 
 
1,298
 
922
 
 
 
 
 
USD 41,910
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
26
Name,
Position
The main conditions of share award plans
Information regarding the reported financial year
 
 
 
 
Opening
balance
During the year
Closing
balance
1
 
Specifi-
cation
of plan
2
 
Perfor-
mance
period
 
3
Award date
5
 
End of
holding
period
6
 
Shares
awarded at
the
beginning
of the year
7
 
Shares
awarded
8
 
Shares vested
11
 
Shares
subject to a
holding
period
 
LTI
2022 - 2024
05/20/2022
05/19/2025
 
952
 
952
 
 
 
 
 
USD 32,958
 
 
Jannik Lindbæk
SSP
2022
01/18/2022
 
 
532
 
 
EVP COM
 
 
 
 
USD 14,122
 
 
 
SUM
 
 
 
 
1,484
 
952
 
 
 
 
 
USD 47,081
 
 
Name,
Position
The main conditions of share award plans
Information regarding the reported financial year
 
 
 
 
Opening
balance
During the year
Closing
balance
1
 
Specifi-
cation
of plan
2
 
Perfor-
mance
period
 
3
Award date
5
 
End of
holding
period
6
 
Shares
awarded at
the
beginning of
the year
7
 
Shares
awarded
8
 
Shares vested
11
 
Shares
subject to a
holding
period
 
SSP
2022
01/18/2022
 
 
455
 
 
Carri Lockhart
 
 
 
 
USD 11,996
 
 
EVP TDI
SUM
 
 
 
 
455
 
 
 
 
 
 
 
USD 11,996
 
 
4.3
 
Total
 
number and value of shares held by the CEC
The number of Equinor shares owned by members of the CEC and/or
 
their close associates is shown
below. Individually,
 
each member of the CEC owned less than 1% of the outstanding Equinor
 
shares.
The voting rights of members of the CEC members as shareholders do
 
not differ from those of ordinary
shareholders.
Ownership of
Equinor shares
(incl. shares owned
by close
associates)
As of 1 Jan.
2022
As of 31 Dec.
2022
Market value as of
31 Dec. 2022, USD
thousand
As of 14 March
2023
Anders Opedal
41,458
46,996
1,725
47,315
Ulrica Fearn
-
-
 
-
-
Torgrim Reitan
-
11,473
421
12,879
Arne Sigve Nylund
15,820
-
 
-
-
Geir Tungesvik
-
17,624
647
18,563
Irene Rummelhoff
25,036
28,152
1,033
29,523
Jannicke Nilsson
56,272
59,380
2,179
60,945
Pål Eitrheim
17,840
19,644
721
19,644
Alasdair Cook
3,738
3,738
137
-
Philippe F. Mathieu
-
4,645
170
5,420
Kjetil Hove
17,017
20,149
740
21,220
Carri Lockhart
8,450
-
 
-
-
Hege Skryseth
-
2,633
97
2,633
Siv Helen Rygh
Torstensen
13,318
15,832
581
17,132
Ana Fonseca Nordang
8,370
-
 
-
-
Aksel Stenerud
-
9,372
344
9,966
 
 
 
 
 
 
 
 
27
Jannik Lindbæk
-
12,542
460
13,367
4.4
 
Performance and AVP
 
awarded to the CEC members in the reported
financial year
 
In accordance with Equinor’s performance framework
 
and remuneration policy, performance in relation
to behaviour goals has formed an equal part to the business performance
 
in the holistic performance
assessment.
 
The assessment of the performance results for 2022 is presented below, including a score
measurement against the set KPI targets and behaviour
 
goals.
 
Each delivery KPI is given a score within a range of 1-5, where 5 is
 
the highest result. Each score
reflects a holistic assessment, where applicable. The holistic assessment
 
may reflect events outside the
control of the CEO or EVPs, such as exceptional fluctuations in commodity
 
prices, changes in global
conditions,
 
the industry operating environment or other relevant context.
 
The overall performance on the behaviour goals is also given a score
 
within the range of 1-5.
Performance on behaviour goals is a qualitative assessment by
 
the board of directors and the CEO, as
applicable, and is supported by the results of employee feedback surveys.
 
The scores are converted into the AVP award percentage, as shown in the below conversion table.
 
As mentioned above, two factors – the threshold and the company
 
performance modifier (“CPM”) - are
applied to the percentage to arrive at the final AVP award pay-out levels,
 
as described above.
Process illustration – numbers are for illustration only
 
exhibit156p28i0
28
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
exhibit156p29i0
29
Conversion table from performance rating to AVP
Select business delivery KPIs (“what” dimension) set at the corporate
 
level are applicable to both CEO
and the EVPs.
 
Table
 
4 - Performance of CEC members in the reported financial year
Corporate delivery KPIs
“WHAT”-dimension – corporate
 
delivery KPIs - total assessment
3.4
Target
Achievements
Assessment
Serious incident frequency
<0.4
0.4
3.3
Upstream CO2 intensity
<8 kg/boe
6.9 kg /boe
3.5
Capex share REN/LCS
>15%
14%
2.8
Relative TSR
Above average
2
nd
 
quartile
3.0
Relative RoACE
1
st
 
quartile
1
st
 
quartile
4.2
Holistic assessment of corporate delivery KPIs:
The final scores for the following KPIs have been adjusted
 
from actual score through the
board of directors' holistic assessment:  
 
1) Final score for Serious incident frequency is increased as the
 
result is best in history,
and with continued improvement from last year and an actual reduction
 
in number of
incidents despite higher activity level 
 
2) Final score for Upstream CO2 intensity has been reduced for positive
 
impact from high
gas production, late start of Peregrino and Snøhvit and start-up of low emitting
 
assets
3) The final score on relative ROACE has been reduced to reflect
 
the impact of delayed
tax payments on the NCS
Additional BA-specific delivery KPIs (“what” dimension) apply
 
to EVPs with business areas
responsibilities.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
30
Select behaviour goals (“how” dimension) are set in relation
 
to both CEO and the EVPs and assessed
on an individual basis. The total score representing the assessment
 
of the results is shown below for
the respective CEC member. The assessment of individual behaviour goals is not disclosed.
“HOW”-dimension – behaviour goals
Demonstrate accountability,
 
visibility, and engagement
 
for safety and
compliance
Build trust in the CEC and Equinor
Transform own organisation to deliver
 
on our common purpose and become a
leading company in the energy transition
Develop strong succession pipeline
The performance results of each member of the CEC with respect
 
to the delivery KPIs and behaviour
goals set for such member are set forth further, together with the resulting AVP award level.
Anders Opedal (CEO)
«WHAT»-dimension
 
– corporate delivery KPIs
3.4
“HOW”-dimension – behaviour goals
3.3
Demonstrate accountability,
 
visibility, and engagement
 
for safety and
compliance
Build trust in the CEC and Equinor
Transform own organisation to deliver
 
on our common purpose and become a
leading company in the energy transition
Develop strong succession pipeline
Total
 
performance assessment for AVP
3.3
AVP award pre company
 
performance modifier
30%
AVP award
Award
outcome AVP
%
Reduction
for threshold
USD (1000)
AVP target
25%
Base salary, USD (1000)
1,031
Award based on performance
evaluation
30%
n/a
309
Adjustment for company modifier
133%
0.33
102
421
The performance assessment included the following holistic considerations,
 
which have
influenced the overall score:
Corporate delivery KPIs:
Ref comments to separate table above on corporate delivery
KPIs
Irene Rummelhoff (EVP MMP)
«WHAT»-dimension
 
– corporate delivery KPIs
3.4
“WHAT”-dimension – business
 
area delivery KPIs
3.5
Target
Achievements
Assessment
Unplanned shutdowns onshore assets
2.50%
3.80%
2.7
Adjusted earnings (MUSD)
>1,500
4,920
5.0
Fixed opex and SG&A (MUSD)
<1,145
1,313
2.8
“HOW”-dimension – behaviour goals
3.3
Demonstrate accountability,
 
visibility, and engagement
 
for safety and
compliance
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
31
Build trust in the CEC and Equinor
Transform own organisation to deliver
 
on our common purpose and become a
leading company in the energy transition
Develop strong succession pipeline
Total
 
performance assessment for AVP
3.4
AVP award pre company
 
performance modifier
33%
AVP award
Award
outcome AVP
%
Reduction
for threshold
USD (1000)
AVP target
25%
Base salary, USD (1000)
450
Award based on performance
evaluation
33%
n/a
149
Adjustment for company modifier
133%
0.33
49
198
The performance assessment included the following holistic considerations,
 
which have
influenced the overall score:
Corporate delivery KPIs:
Ref comments to separate table above on corporate delivery
KPIs
Jannicke Nilsson (EVP SSU)
«WHAT»-dimension
 
– corporate delivery KPIs
3.4
“HOW”-dimension – behaviour goals
3.1
Demonstrate accountability,
 
visibility, and engagement
 
for safety and
compliance
Build trust in the CEC and Equinor
Transform own organisation to deliver
 
on our common purpose and become a
leading company in the energy transition
Develop strong succession pipeline
Total
 
performance assessment for AVP
3.2
AVP award pre company
 
performance modifier
28%
AVP award
Award
outcome AVP
%
Reduction
for threshold
USD (1000)
AVP target
25%
Base salary, USD (1000)
370
Award based on performance
evaluation
28%
n/a
104
Adjustment for company modifier
133%
0.33
34
138
The performance assessment included the following holistic considerations,
 
which have
influenced the overall score:
Corporate delivery KPIs:
Ref comments to separate table above on corporate delivery
KPIs
Pål Eitrheim (EVP REN)
«WHAT»-dimension
 
– corporate delivery KPIs
3.4
“WHAT”-dimension – business
 
area delivery KPIs
2.8
Target
Achievements
Assessment
Production based availability (PBA)
>96%
93.3 %
2.8
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
32
Capacity accessed offshore
>3 GW
2 GW
2.9
Improvement in LCOE
>2%
-1%
2.6
“HOW”-dimension – behaviour goals
3.2
Demonstrate accountability,
 
visibility, and engagement
 
for safety and
compliance
Build trust in the CEC and Equinor
Transform own organisation to deliver
 
on our common purpose and become a
leading company in the energy transition
Develop strong succession pipeline
Total
 
performance assessment for AVP
3.1
AVP award pre company
 
performance modifier
27%
AVP award
Award
outcome AVP
%
Reduction
for threshold
USD (1000)
AVP target
25%
Base salary, USD (1000)
405
Award based on performance
evaluation
27%
n/a
109
Adjustment for company modifier
133%
0,33
36
146
The performance assessment included the following holistic considerations,
 
which have
influenced the overall score:
Corporate delivery KPIs:
Ref comments to separate table above on corporate delivery
KPIs
BA-specific KPIs:
 
The final scores for the following KPIs have been adjusted
 
from actual
score through the CEO`s holistic assessment of the performance:
 
The score for accessed wind capacity KPI has been increased
 
slightly because capital
discipline has been desirable in a very competitive market
Kjetil Hove (EVP EPN)
«WHAT»-dimension
 
– corporate delivery KPIs
3.4
“WHAT”-dimension – business
 
area delivery KPIs
3.3
Target
Achievements
Assessment
Production
>1,425
1,387
3.3
UPC USD/boe
<5
5.8
3.3
Net cash flow @65 USD/bbl
>13 BUSD
12.5 BUSD
3.3
“HOW”-dimension – behaviour goals
3.3
Demonstrate accountability,
 
visibility, and engagement
 
for safety and
compliance
Build trust in the CEC and Equinor
Transform own organisation to deliver
 
on our common purpose and become a
leading company in the energy transition
Develop strong succession pipeline
Total
 
performance assessment for AVP
3.3
AVP award pre company
 
performance modifier
30%
AVP award
Award
outcome AVP
%
Reduction
for threshold
USD (1000)
AVP target
25%
Base salary, USD (1000)
506
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
33
Award based on performance
evaluation
30%
n/a
152
Adjustment for company modifier
133%
0.33
50
202
The performance assessment included the following holistic considerations,
 
which have
influenced the overall score:
Corporate delivery KPIs:
Ref comments to separate table above on corporate delivery
KPIs
BA-specific KPIs:
 
The final scores for the following KPIs have been adjusted
 
from actual
score through the CEO`s holistic assessment of the performance:
 
1) Final score for Production is increased as a result of strong gas deliveries
 
from NCS to
Europe
2) Final score for Unit production cost is increased as a result of
 
market effects from
increased Co2 and electricity cost
3) Net cash flow at 65 is increased as a result of market effects on cost
Siv Helen Rygh Torstensen (EVP LEG)
«WHAT»-dimension
 
– corporate delivery KPIs
3.4
“HOW”-dimension – behaviour goals
3.1
Demonstrate accountability,
 
visibility, and engagement
 
for safety and
compliance
Build trust in the CEC and Equinor
Transform own organisation to deliver
 
on our common purpose and become a
leading company in the energy transition
Develop strong succession pipeline
Total
 
performance assessment for AVP
3.2
AVP award pre company
 
performance modifier
28%
AVP award
Award
outcome AVP
%
Reduction
for threshold
USD (1000)
AVP target
25%
Base salary, USD (1000)
321
Award based on performance
evaluation
28%
n/a
90
Adjustment for company modifier
133%
0,33
30
120
The performance assessment included the following holistic considerations,
 
which have
influenced the overall score:
Corporate delivery KPIs:
Ref comments to separate table above on corporate delivery
KPIs
Geir Tungesvik (EVP PDP)
«WHAT»-dimension
 
– corporate delivery KPIs
3.4
“WHAT”-dimension – business
 
area delivery KPIs
2.9
Target
Achievements
Assessment
Number of new wells
107
94
2.6
Break-even price DG1-DG3
(USD/boe)
<=37
40.8
3.0
Estimate development DG3/4
<105%
109%
3.1
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
34
“HOW”-dimension – behaviour goals
3.1
Demonstrate accountability,
 
visibility, and engagement
 
for safety and
compliance
Build trust in the CEC and Equinor
Transform own organisation to deliver
 
on our common purpose and become a
leading company in the energy transition
Develop strong succession pipeline
Total
 
performance assessment for AVP
3.1
AVP award pre company
 
performance modifier
27%
AVP award
Award
outcome AVP
%
Reduction
for threshold
USD (1000)
AVP target
25%
Base salary, USD (1000)
406
Award based on performance
evaluation
27%
n/a
110
Adjustment for company modifier
133%
0.33
36
146
The performance assessment included the following holistic considerations,
 
which have
influenced the overall score:
Corporate delivery KPIs:
Ref comments to separate table above on corporate delivery
KPIs
BA-specific KPIs:
 
The final scores for the following KPIs have been adjusted
 
from actual
score through the CEO`s holistic assessment of the performance:
 
1) Break-even price DG1-DG3 adjusted due to unprecedented market
 
increase
2) Estimate DG3-DG4 is increased due to the impact of currency
Torgrim Reitan (CFO)
«WHAT»-dimension
 
– corporate delivery KPIs
3.4
“HOW”-dimension – behaviour goals
3.3
Demonstrate accountability,
 
visibility, and engagement
 
for safety and
compliance
Build trust in the CEC and Equinor
Transform own organisation to deliver
 
on our common purpose and become a
leading company in the energy transition
Develop strong succession pipeline
Total
 
performance assessment for AVP
3.3
AVP award pre company
 
performance modifier
30%
AVP award
Award
outcome AVP
%
Reduction
for threshold
USD (1000)
AVP target
25%
Base salary, USD (1000)
485
Award based on performance
evaluation
30%
n/a
146
Adjustment for company modifier
133%
0,33
48
194
The performance assessment included the following holistic considerations,
 
which have
influenced the overall score:
Corporate delivery KPIs:
Ref comments to separate table above on corporate delivery
KPIs
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
35
Ana Fonseca Nordang (EVP PO)
«WHAT»-dimension
 
– corporate delivery KPIs
-
 
“HOW”-dimension – behaviour goals
-
 
Demonstrate accountability,
 
visibility, and engagement
 
for safety and
compliance
Build trust in the CEC and Equinor
Transform own organisation to deliver
 
on our common purpose and become a
leading company in the energy transition
Develop strong succession pipeline
Total
 
performance assessment for AVP
-
 
AVP award pre company
 
performance modifier
25%
AVP award
Award
outcome AVP
%
Reduction
for threshold
USD (1000)
AVP target
25%
Base salary, USD (1000)
326
Award based on performance
evaluation
25%
n/a
82
Adjustment for company modifier
133%
0.33
27
109
The performance assessment included the following holistic considerations,
 
which have
influenced the overall score:
Due to short period in role in 2022 scores not provided.
Aksel Stenerud (EVP PO)
«WHAT»-dimension
 
– corporate delivery KPIs
3.4
“HOW”-dimension – behaviour goals
3.1
Demonstrate accountability,
 
visibility, and engagement
 
for safety and
compliance
Build trust in the CEC and Equinor
Transform own organisation to deliver
 
on our common purpose and become a
leading company in the energy transition
Develop strong succession pipeline
Total
 
performance assessment for AVP
3.2
AVP award pre company
 
performance modifier
28%
AVP award
Award
outcome AVP
%
Reduction
for threshold
USD (1000)
AVP target
25%
Base salary, USD (1000)
322
Award based on performance
evaluation
28%
n/a
90
Adjustment for company modifier
133%
0.33
30
120
The performance assessment included the following holistic considerations,
 
which have
influenced the overall score:
Corporate delivery KPIs:
Ref comments to separate table above on corporate delivery
KPIs
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
36
Elisabeth Birkeland Kvalheim (acting EVP TDI)
«WHAT»-dimension
 
– corporate delivery KPIs
3.4
“WHAT”-dimension – business
 
area delivery KPIs
2.9
Target
Achievements
Assessment
Low Carbon/Renewable R&D
> 2021 (32%)
36%
3.3
Net multiple of Money Invested
>1
<1
2.7
TDI task responsibility – Cost, MNOK,
100%
<8,000
10,088
2.8
“HOW”-dimension – behaviour goals
3.3
Demonstrate accountability,
 
visibility, and engagement
 
for safety and
compliance
Build trust in the CEC and Equinor
Transform own organisation to deliver
 
on our common purpose and become a
leading company in the energy transition
Develop strong succession pipeline
Total
 
performance assessment for AVP
3.2
AVP award pre company
 
performance modifier
28%
AVP award
Award
outcome AVP
%
Reduction
for threshold
USD (1000)
AVP target
25%
Base salary, USD (1000)
261
Award based on performance
evaluation
28%
n/a
73
Adjustment for company modifier
133%
0.33
24
97
The performance assessment included the following holistic considerations,
 
which have
influenced the overall score:
Corporate delivery KPIs:
Ref comments to separate table above on corporate delivery
KPIs
Hege Skryseth (EVP TDI)
«WHAT»-dimension
 
– corporate delivery KPIs
3.4
“WHAT”-dimension – business
 
area delivery KPIs
2.9
Target
Achievements
Assessment
Low Carbon/Renewable R&D
> 2021 (32%)
36%
3.3
Net multiple of Money Invested
>1
<1
2.7
TDI task responsibility – Cost, MNOK,
100%
<8,000
10,088
2.8
“HOW”-dimension – behaviour goals
3.3
Demonstrate accountability,
 
visibility, and engagement
 
for safety and
compliance
Build trust in the CEC and Equinor
Transform own organisation to deliver
 
on our common purpose and become a
leading company in the energy transition
Develop strong succession pipeline
Total
 
performance assessment for AVP
3.2
AVP award pre company
 
performance modifier
28%
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
37
AVP award
Award
outcome AVP
%
Reduction
for threshold
USD (1000)
AVP target
25%
Base salary, USD (1000)
417
Award based on performance
evaluation
28%
n/a
117
Adjustment for company modifier
133%
0.33
39
155
The performance assessment included the following holistic considerations,
 
which have
influenced the overall score:
Corporate delivery KPIs:
Ref comments to separate table above on corporate delivery
KPIs
Jannik Lindbæk (EVP COM)
«WHAT»-dimension
 
– corporate delivery KPIs
3.4
“HOW”-dimension – behaviour goals
3.1
Demonstrate accountability,
 
visibility, and engagement
 
for safety and
compliance
Build trust in the CEC and Equinor
Transform own organisation to deliver
 
on our common purpose and become a
leading company in the energy transition
Develop strong succession pipeline
Total
 
performance assessment for AVP
3.2
AVP award pre company
 
performance modifier
28%
AVP award
Award
outcome AVP
%
Reduction
for threshold
USD (1000)
AVP target
25%
Base salary, USD (1000)
317
Award based on performance
evaluation
28%
n/a
89
Adjustment for company modifier
133%
0.33
29
118
The performance assessment included the following holistic considerations,
 
which have
influenced the overall score:
Corporate delivery KPIs:
Ref comments to separate table above on corporate delivery
KPIs
4.5
 
Key performance indicators and behaviour goals forming
 
the basis for AVP
for the CEC in 2023
 
The business delivery dimension (“what”) for the variable remuneration
 
(performance year 2023) for the
CEC members will be based on an assessment against the following
 
common corporate KPIs:
 
-
 
Serious Incident Frequency: 0.3
 
or better
-
 
CO
2
 
intensity for the upstream portfolio: 8 kg CO
2
/boe or better
 
-
 
Relative total shareholder return: ranked better than peer average
-
 
Relative RoACE: Ranked in first quartile among peers
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
38
-
 
Unit production cost (UPC): under 6.0 USD/boe*
 
-
 
Renewable (REN) power production*: not disclosed **
 
(*) only apply to the CEO and EVPs without business area responsibilities
For EVPs with business area responsibilities, the assessment of
 
the business delivery dimension will in
addition
 
be made against the following KPIs:
Business area
KPI
Unit
Target
EPN
Production
kboe/d
1,446
 
UPC
nominal USD/boe
5.8
 
Break-even price (CMU portfolio)
USD/bbl
<35
EPI
Production
kboe/d
677
 
UPC
nominal USD/boe
6.5
 
Break-even price (CMU portfolio)
USD/bbl
<35
MMP
Production efficiency
%
not disclosed**
 
 
Net Operating income (ex derivatives)
bn USD
not disclosed**
 
 
Fixed opex & SG&A
mill USD
1,285
REN
REN power generation
TWh
not disclosed*
 
 
NOI adjusted
mill USD
> -200
PDP
Number of wells
number
104
 
Break-even price (CMU portfolio)
USD/bbl
<35
 
Estimate development DG3-DG4
%
100%
TDI
Low carbon R&D
 
>30%
 
Software consolidation progress
 
50%
 
TDI task responsibility cost savings
NOK mill, 100%
500
(**) Not disclosed due to commercial sensitivity
The behaviour dimension (“how”) will be based on an individual assessment
 
against the following goals:
 
-
 
Demonstrate accountability, visibility,
 
and engagement for safety, security and compliance
 
-
 
Build trust in Equinor
-
 
Transform the organization to deliver on our common purpose and become a leading company
 
in
the energy transition
-
 
Develop strong and diverse succession pipeline
5
 
Remuneration and company performance for 2017-2022
5.1
 
Comparative tables
 
over the remuneration and company performance
compared to the last five reported financial years
 
Table 5 - Comparative table over the remuneration and company performance over the last five reported financial years
(RFY)
Executive remuneration for 2018-2022
All amounts in USD
Remuneration
2018
2019
2020
2021
2022
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
39
Anders Opedal, CEO
Total remuneration and %
change vs previous year
1,171,41
0
-
881,029
-
24.79%
814,098
-7.60%
2,055,023
152.43%
2,042,382
-0.62%
Base salary % increase in annual
salary review and on other
adjustments
-
-
4.00%
-
0.00%
133.30%
3.50%
-
4.90%
-
AVP % pre and post threshold
and company performance
modifier
-
-
28.00%
23.24%
0,00%
0,00%
30.00%
45.00%
30.00%
39.90%
LTI % pre and post threshold
 
-
-
25.00%
25.00%
25.00%
25.00%
30.00%
15,00%
30.00%
30.00%
Remuneration
2018
2019
2020
2021
2022
Irene Rummelhoff, EVP MMP
Total remuneration and %
change vs previous year
924,926
28.34%
826,342
-
10.66%
681,363
-17.54%
923,578
35.55%
960,784
4.03%
Base salary % increase in annual
salary review and on other
adjustments
-
25.10%
3.80%
-
-
-
3.00%
5.40%
4.90%
-
AVP % pre and post threshold
and company performance
modifier
29.00%
43.50%
26.00%
21.58%
-
-
28.00%
42.00%
33.00%
43.89%
LTI % pre and post threshold
 
25.00%
25.00%
25.00%
25.00%
25.00%
25.00%
25.00%
12.50%
25.00%
25.00%
Arne Sigve Nylund, EVP PDP
Total remuneration and %
change vs previous year
1,001,19
7
19.27%
889,200
-
11.19%
736,354
-17.19%
999,976
35.80%
1,111,160
11.12%
Base salary % increase in annual
salary review and on other
adjustments
11.00%
-
4.20%
-
-
-
3.00%
-
-
-
AVP % pre and post threshold
and company performance
modifier
31.00%
46.50%
26.00%
21.58%
-
-
28.00%
42.00%
-
-
LTI % pre and post threshold
 
25.00%
25.00%
25.00%
25.00%
25.00%
25.00%
25.00%
12.50%
25.00%
25.00%
Jannicke Nilsson, EVP SSU
Total remuneration and %
change vs previous year
890,465
15.29%
757,055
-
14.98%
623,702
-17.61%
829,810
33.05%
844,012
1.71%
Base salary % increase in annual
salary review and on other
adjustments
3.10%
-
3.60%
-
-
-
3.00%
5.40%
4.50%
-
AVP % pre and post threshold
and company performance
modifier
26.00%
39.00%
23.00%
19.09%
-
-
27.00%
40.50%
28.00%
37.24%
LTI % pre and post threshold
 
25.00%
25.00%
25.00%
25.00%
25.00%
25.00%
25.00%
12.50%
25.00%
25.00%
Pål Eitrheim, EVP REN
Total remuneration and %
change vs previous year
807,881
-
669,000
-
17.19%
524,113
-21.66%
796,048
51.88%
782,549
-1.70%
Base salary % increase in annual
salary review and on other
adjustments
-
-
3.40%
-
-
-
4.00%
17.20%
4.90%
-
AVP % pre and post threshold
and company performance
modifier
-
-
26.00%
21.58%
-
-
31.00%
46.50%
27.00%
35.91%
LTI % pre and post threshold
 
-
-
25.00%
25.00%
25.00%
25.00%
25.00%
12.50%
25.00%
25.00%
Alasdair Cook, EVP EPI
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
40
Total remuneration and %
change vs previous year
1,331,01
5
-
1,364,022
2.48%
1,037,27
2
-23.95%
1,912,255
84.35%
1,643,412
-14.06%
Base salary % increase in annual
salary review and on other
adjustments
-
-
5.95%
-
-
-
3.50%
23.60%
4.50%
0
AVP % pre and post threshold
and company performance
modifier
-
-
43.00%
35.69%
-
-
48.00%
72.00%
-
LTI % pre and post threshold
 
-
-
70.00%
93.33%
70.00%
85.40%
70.00%
85.40%
70.00%
85.40%
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
41
All amounts in USD
Remuneration
2018
2019
2020
2021
2022
Kjetil Hove, EVP EPN
Total remuneration and %
change vs previous year
-
-
-
-
-
-
1,004,283
-
1,055,271
5.08%
Base salary % increase in annual
salary review and on other
adjustments
-
-
-
-
-
-
-
5.05%
-
AVP % pre and post threshold
and company performance
modifier
-
-
-
-
-
-
32.00%
48.00%
30.00%
39.90%
LTI % pre and post threshold
 
-
-
-
-
-
-
25.00%
12.50%
25.00%
25.00%
Carri Lockhart, EVP TDI
Total remuneration and %
change vs previous year
-
-
-
-
-
-
2,018,761
-
3,367,960
66.83%
Base salary % increase in annual
salary review and on other
adjustments
-
-
-
-
-
-
-
-
-
-
AVP % pre and post threshold
and company performance
modifier
-
-
-
-
-
-
50.00%
75.00%
-
-
LTI % pre and post threshold
 
-
-
-
-
-
-
70.00%
85.40%
70.00%
85.40%
Ulrica Fearn, EVP and CFO
Total remuneration and %
change vs previous year
-
-
-
-
-
-
1,821,237
-
1,093,432
-39.96%
Base salary % increase in annual
salary review and on other
adjustments
-
-
-
-
-
-
-
-
4.90%
-
AVP % pre and post threshold
and company performance
modifier
-
-
-
-
-
-
30.00%
45.00%
-
-
LTI % pre and post threshold
 
-
-
-
-
-
-
25.00%
12.50%
25.00%
25.00%
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
42
All amounts in USD
Remuneration
2018
2019
2020
2021
2022
Torgrim Reitan, EVP CFO
Total remuneration and %
change vs previous year
1,206,16
5
2.28%
904,980
-
24.97%
766,448
-15.31%
-
1,027,357
-
Base salary % increase in annual
salary review and on other
adjustments
7.77%
3.73%
-
-
AVP % pre and post threshold
and company performance
modifier
30.00%
45.00%
27.00%
22.41%
30.00%
39.90%
LTI % pre and post threshold
 
25.00%
25.00%
25.00%
25.00%
25.00%
25.00%
25.00%
25.00%
Siv Helen Rygh Torstensen, EVP LEG
Total remuneration and %
change vs previous year
-
-
-
-
-
-
645,511
691,436
7.11%
Base salary % increase in annual
salary review and on other
adjustments
-
-
-
-
-
-
4.90%
-
AVP % pre and post threshold
and company performance
modifier
-
-
-
-
-
-
27.00%
40.50%
28.00%
37.24%
LTI % pre and post threshold
 
-
-
-
-
-
-
25.00%
12.50%
25.00%
25.00%
Ana Fonseca Nordang, EVP PO
Total remuneration and %
change vs previous year
-
-
-
-
-
-
670,712
-
682,030
1.69%
Base salary % increase in annual
salary review and on other
adjustments
-
-
-
-
-
-
-
-
-
-
AVP % pre and post threshold
and company performance
modifier
-
-
-
-
-
-
27.00%
40.50%
25.00%
33.25%
LTI % pre and post threshold
 
-
-
-
-
-
-
25.00%
12.50%
25.00%
25.00%
Geir Tungesvik,
 
EVP PDP
-
-
-
-
-
-
-
-
Elisabeth Birkeland Kvalheim,
Acting EVP TDI
-
-
-
-
-
-
-
-
Hege Skryseth,
 
EVP TDI
-
-
-
-
-
-
-
-
Aksel Stenerud,
 
EVP PO
-
-
-
-
-
-
-
-
Jannik Lindbæk,
 
EVP COM
-
-
-
-
-
-
-
-
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
43
Notes to the table “Executive remuneration for 2017-2022”:
-
 
Total
 
remuneration consists of taxable compensation, non-taxable benefits
 
in kind, and estimated
pension cost for the years 2017-2020
-
 
For the cash-based plans, payment of LTI is made 3 years after the grant. The “post” percentage is
relative to base salary at the time of the grant.
 
Company performance - effect on
AVP and LTI
2018
2019
2020
2021
2022
AVP
LTI
AVP
LTI
AVP
LTI
AVP
LTI
AVP
LTI
Threshold
-
-
-
-
50 %
reduct.
-
-
50 %
reduct.
-
-
Company performance modifier
150%
-
83%
-
133%
-
150%
-
133%
-
All amounts in USD
Average remuneration on a full-time
equivalent basis of employees
2018
2019
2020
2021
2022
Equinor ASA
4)
Average base salary and %
change vs previous year, based
on USD amounts
94,903
4.70%
90,260
-4.90%
86,229
-4.50%
95,893
11.20%
88,923
-7.27%
Change in average base salary
vs previous year, based on NOK
amounts
-
3.00%
-
3.00%
-
1.60%
-
2.00%
-
3.40%
Average total remuneration and
% change vs previous year,
based on USD amounts
133,656
7.00%
123,626
-7.50%
115,137
-6.90%
135,597
17.80%
144,868
6.84%
Change in average total
remuneration vs previous year,
based on NOK amounts
-
5.30%
-
0.20%
-
-0.90%
-
8.10%
-
19.2%
General salary increase frame
-
2.90%
-
3.50%
-
0.80%
-
3.50%
-
4.90%
General bonus %
-
8.50%
-
4.50%
-
3.50%
-
10.50%
-
9.30%
AVP % range from manager to
SVP pre and post company
performance modifier and
threshold
11.25% -
17.5%
16.88% -
26.25%
11.25% -
17.5%
9.34% -
14.53%
11.25% -
17.5%
7.48% -
11.64%
11.25% -
17.5%
16.88% -
26.25%
11.25%-
17.50%
14.96%-
23.28%
Notes to the table “Average remuneration on a full-time equivalent basis of
 
employees”:
●
 
Offshore workers with 2-4 schedule reported as FTE 100%
●
 
Annual salary increase is affected by the NOK/USD exchange rate
●
 
Holiday and bonus pay are included for the year of accrual
●
 
Annual total remuneration increase is affected by bonus and any bonus shares
 
from the SSP or
LTI
●
 
Overtime allowance is not included. Pension is included as of 2022
6
 
Statement by the board of directors on the remuneration report
44
The board of directors has today considered and approved the
 
remuneration report of Equinor for the
financial year 1 January - 31 December 2022.
 
The remuneration report has been prepared in accordance with Norwegian
 
Public Limited Liability
Companies Act, section 6-16b and regulation 2020-12-
11
-2730 and the Norwegian Accounting Act
section 7-31b.
In our opinion, the remuneration report is in accordance with
 
the remuneration policy adopted at the
annual general meeting, and is free from material misstatement and omissions,
 
whether due to fraud or
error.
The remuneration report will be presented for an advisory vote at
 
the annual general meeting.
Oslo, 19
 
March 2023
The Board of directors of Equinor
 
Jon Erik Reinhardsen,
 
Chair
Anne Drinkwater, Deputy-chair
Bjørn Tore
 
Godal
 
Hilde Møllerstad
 
Per Martin Labråthen
 
Tove
 
Andersen
Rebekka Glasser Herlofsen
 
Finn Bjørn Ruyter
 
Stig Lægreid
 
Jonathan Lewis
 
Michael D. Lewis
 
45
7
 
Independent auditor’s statement on the remuneration report
[Removed from Exhibit 15.6 as it does not form part of Equinor’s
 
Annual Report on Form 20-F as filed
with the SEC.]
 
 
 
 
 
 
 
 
 
 
46
8
 
Appendix: Executive remuneration policy 2021
8.1
 
Remuneration to the board of directors
 
Approach to setting fees
Basis of fees
Other items
The remuneration to the board
and its committees is decided
by the corporate assembly,
based on a recommendation
from the nomination
committee.
The board members have an annual,
fixed remuneration, except for deputy
members (only elected for employee-
elected board members) who receive
remuneration per meeting attended.
Separate rates are set for the board's
chair, deputy chair and other members.
Separate rates are also adopted for the
board's committees, with similar
differentiation between the chair and the
other members of each committee.
The employee-elected members of the
board receive the same remuneration as
the shareholder-elected members. The
board receives its remuneration by cash
payment.
The board members from outside Scandinavia and
outside Europe, respectively, receive separate
travel allowances for each meeting attended.
Remuneration for board membership is not linked to
performance and no share or option programmes or
similar structures are in place.
Employee-elected board members may participate
in variable pay, pension and benefit programs
according to their location and grade in line with
other employees.
None of the shareholder-elected board members
have a pension scheme or agreement concerning
pay after termination of their office with the
company.
If shareholder-elected members of the board and/or
companies they are associated with should take on
specific assignments for Equinor in addition to their
board membership, this will be disclosed to the full
board.
8.2
 
Remuneration to the corporate assembly
 
Approach to setting fees
Basis of fees
The remuneration to the corporate assembly is decided by the
general meeting, based on a recommendation from the
nomination committee
The members have an annual, fixed remuneration, except for
deputy members who receive remuneration per meeting
attended.
Separate rates are set for the corporate assembly’s chair,
deputy chair and other members. The employee-elected
members of the corporate assembly receive the same
remuneration as the shareholder-elected members.
8.3
 
Remuneration to the CEC
The board of directors’ complete remuneration policy and report for executive personnel follows.
 
Remuneration policy
 
The following guidelines for remuneration of Equinor’ corporate
executive committee proposed by the board of directors were
approved by the 20212 annual general meeting, pursuant to
the Norwegian Public Limited Liability Companies Act, section
6-16 a and supplementing regulations. The policy also includes
compensation to members of the board of directors and the
corporate assembly employed by the company, which is
explained in the above section “ Remuneration to the board of
directors and corporate assembly”. The policy is subject to
approval by the annual general meeting at every material
change and, in any case, at least every fourth year.
 
Equinor’s remuneration policy and terms are aligned with the
company’s overall strategy, values, people policy and
performance-oriented framework. Our rewards and recognition
for executives are designed to attract and retain the right
people; people who are committed to deliver on our business
strategy and able to adapt to a changing business
47
environment. Equinor’s remuneration framework contributes to
the business strategy, long-term interests and sustainability of
the company.
 
A key role for the board of directors is to ensure that executive
compensation is competitive, but not market leading, in the
markets where we operate. The board is committed to
ensuring that executive compensation is fair and aligned with
our overall remuneration philosophy and compensation levels
in the company, and in line with shareholders’ interests.
The remuneration policy is an integrated part of our values-
based performance framework. It has been designed to:
●
 
Contribute to the business strategy, long-term
interests and sustainability of the company
●
 
Strengthen the common interests of employees in the
Equinor group and its shareholders
●
 
Reflect the company’s overall performance and
financial results
●
 
Be competitive and aligned with local markets
●
 
Equally reward and recognise “What” we deliver and
“How” we deliver
 
●
 
Differentiate on the basis of responsibilities and
performance
●
 
Be acknowledged as fair, transparent, consistent and
non-discriminatory
●
 
Promote collaboration and teamwork
●
 
Fully align with our values and HSE standards
●
 
Promote continuous improvement and a sustainable
cost level
 
The decision-making process
 
The decision-making process for implementing or changing our
remuneration policy, and the determination of salaries and
other remuneration for the corporate executive committee, are
in accordance with the provisions of the Norwegian public
limited liability companies act sections 5-6 and 6-16 a and the
board’s rules of procedure. The board of director’s rules of
procedure are available at www.equinor.com/board.
The board of directors has appointed a designated
compensation and executive development committee. The
compensation and executive development committee is a
preparatory body for the board of directors. The committee’s
main objective is to assist the board of directors in its work
relating to the terms of employment for Equinor’s chief
executive officer and the main principles and strategy for the
remuneration and leadership development of our senior
executives. The board of directors determines the chief
executive officer’s salary and other terms of employment. The
committee shall prepare a proposal for new guidelines at every
material change and, in any case, every fourth year and submit
it to the general meeting for resolution. The guidelines shall be
in force until new guidelines have been adopted by the general
meeting.
 
The compensation and executive development committee
answers to the board of Equinor ASA for the performance of its
duties. The work of the committee in no way alters the
responsibilities of the board of directors or the individual board
members.
For further details about the roles and responsibilities of the
compensation and executive development committee, please
refer to the committee’s instructions available at
www.equinor.com/compensationcommittee.
Equinor purpose, vision and overall strategy
Equinor’s purpose is turning natural resources into energy for
people and progress for society, and our vision is to shape the
future of energy. We are strongly committed to creating
shareholder value and with a leading role in the energy
transition towards a low-carbon future.
 
While our strategic pillars of “always safe”, “high value” and
“low carbon” remain firm, we will further strengthen in the areas
of a) an optimised oil & gas portfolio, b) a faster growing
renewable business, c) expanding our low-carbon solutions
business.
 
Within all areas, technology and innovation will be key
accelerators to drive value and improved performance. We will
use our strengths and experience within the oil & gas portfolio
as a foundation for developing offshore wind at scale,
establishing new value chains, and for developing new low
carbon energy sources.
Equinor’s performance framework and the
link to business strategy, long-term interests
and sustainability of the company
Our performance framework translates the company vision,
values and strategy into actions and results for the company,
its units, teams and every leader and employee.
 
Performance is evaluated in two dimensions; “What” we deliver
and “How” we deliver. This is the core of our values-based
performance culture and means that delivery (“what”) and
behaviour (“how”) are equally weighted when recognising and
rewarding individual performance.
 
“What” we deliver (business delivery) is defined through the
company’s performance framework “Ambition to Action”, which
addresses strategic objectives, key performance Indicators
(KPIs) and actions across the five perspectives; Safety,
Security and Sustainability, People and Organisation,
Operations, Market and Finance. Generally, Equinor believes
in setting ambitious targets to inspire and drive strong
performance. Each year individual performance goals (“what”)
based on the company’s “Ambition to Action” are established
for the CEO and the executive vice presidents.
The board decides annually a set of strategic objectives and
KPIs that will form basis for the assessment of the business
delivery dimension (“What”). These KPIs and related targets for
the upcoming performance year shall be disclosed in the
annual remuneration report. Examples of such KPIs are
Serious Incident Frequency (SIF), CO2 intensity for the
upstream portfolio, Levelised cost of energy (LCOE),
Production efficiency (PE), Production based availability (PBA),
Relative Total Shareholder Return (TSR), Relative ROACE,
Improvement impact etc.
48
 
Equinor, Annual Report and Form 20-F 2021
 
Goals on “How” we deliver are based on Equinor’s core values
and leadership principles and address the behaviour required
and expected to achieve the delivery goals. We believe in
developing a strong leadership and culture recognised by our
values, driving the long-term and sustainable success of the
company. The CEO and the executive vice presidents have
individual behaviour goals within prioritised behaviour themes
such as safety and compliance, empowerment, diversity and
inclusion, collaboration and sustainability and climate.
Performance evaluation is holistic, involving both measurement
and assessment. Significant changes in assumptions are taken
into account, as well as target ambition levels, sustainability of
delivered results and strategic contribution.
The balanced approach, which involves a broad set of goals
defined in relation to both “What” and “How” dimensions and
an overall performance evaluation, significantly reduces the
likelihood that remuneration policies may incentivise excessive
risk-taking or have other material adverse effects.
 
The remuneration concept for the corporate executive
committee Equinor’s remuneration for the corporate executive
committee consists of the following core elements;
●
 
Fixed remuneration: base salary and as applicable
fixed salary addition
 
●
 
Variable pay: annual variable pay (AVP) and long-
term incentive (LTI)
●
 
Benefits: primarily pension, insurance and share
savings plan
The following table illustrate how the reward policy is translated
into our key remuneration elements.
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
49
Main elements - Equinor executive remuneration
Remuneration
element
 
Objective
Award level
 
Performance criteria
Base
salary
Attract and retain the right
individuals by providing
competitive but not
market-leading terms.
We offer base salary levels which are aligned
 
with and
differentiated according to the individual's
responsibility, performance
 
and contribution to
company’s goals. The level is competitive
 
in the
markets in which we operate.
 
The base salary is normally subject
to annual review based on an
evaluation of the individual’s
performance and contribution to
the company’s goals.
Fixed
salary
addition
The fixed salary addition is
paid in lieu of pension
accrual above 12G, applied
as a supplementing fixed
remuneration element to
be competitive in the
market.
Members of the corporate executive committee
employed by Equinor ASA prior to 1 September 2017,
that have taken up their first position in the CEC after
13 February 2015, receive a fixed salary addition in
lieu of pension accrual above 12G3 with reference to
the section on pension and insurance scheme.
No performance criteria are linked
to the fixed salary addition. The
fixed salary addition is not
pensionable and does not form
basis for variable pay.
Annual
variable
pay (AVP)
Encourage our pay for
performance culture and
individual’s contribution to
the company’s business
strategy. Rewarding
individuals for annual
achievement of business
objectives, both the
“What” and the “How”.
Members of the corporate executive committee
employed by Equinor ASA are from performance year
2022 entitled to annual variable pay ranging from 0 –
45% of their base salary. Target
 
4
 
value is 25%. For
members of the CEC employed outside the Norwegian
market, see section below on remuneration policy for
international executives.
The threshold principles and the company
performance modifier are applied (see explanations
below).
The company reserves the right to recover all or
 
part
of the annual bonus, if performance data is
subsequently proven to be misstated.
 
Performance is measured over one
financial year and is based on the
achievement of annual
performance goals (“How” and
“What” to deliver), in order to
create long-term and sustainable
shareholder value. Assessment of
goals defined in the individual’s
performance contract including
objectives related to selected KPI’s
on the balanced scorecard
constitute the basis for annual
variable pay.
 
Long-term
incentive
(LTI)
Strengthen the alignment
of top management and
shareholders’ long-term
interests and sustainability
of the company. Retention
of key executives.
 
For members of the corporate executive committee
employed by Equinor ASA, the LTI
 
is calculated as a
portion of the participant’s base salary.
 
On behalf of
the participant, the company acquires shares
equivalent to the net annual grant amount. The shares
are subject to a three-year lock-in period and then
released for the participant’s disposal. If
 
the lock-in
obligations are not fulfilled, the executive has to pay
back the gross value of the locked-in shares limited
 
to
the gross value of the grant amount.
The level of the annual LTI reward
 
for the CEC
members employed by Equinor ASA is in the range
 
of
25-30% of the base salary. For
 
members of the CEC
employed outside the Norwegian market, see section
below on remuneration policy for international
executives.
The threshold principles are applied to the annual
grant. The company performance modifier is not
applied to the LTI in Equinor
 
ASA.
In Equinor ASA, LTI participation
and grant level are reflective of the
level and impact of the position
and company performance as
reflected by the threshold.
Pension &
insurance
schemes
Provide competitive
postemployment and other
benefits.
The company offers a general occupational pension
plan and insurance scheme aligned with local
markets. Reference is made to the section on pension
and insurance scheme.
N/A
 
Employee
share
savings
programme
(SSP)
Align and strengthen
employee and
shareholders’ interests
and remunerate for long
term commitment and
value creation.
Eligibility extends to all employees at Equinor and in
all markets, subject to local legislation. Participants
can purchase shares up to 5% of base salary.
 
With effect from 2022 share
savings, bonus shares from
the share saving programme will
be awarded to the CEO and EVPs
after a lock in
period of 3 calendar years after
the year of saving.
Other
taxable and
non-
taxable
benefits
Attract and retain the right
individuals by providing
competitive but not
market-leading terms.
The members of the corporate executive committee
have benefits in-kind such as company car and
 
health
checks. They are also eligible for participation in the
share saving scheme as described above, and they
take part in the general benefit and welfare program of
the company.
N/A
3
 
G represents the basic amount of the Norwegian
 
social security system. 1G per 31 December 2022
 
equals NOK 111 477..
4
 
Target value reflects satisfactory deliveries according to agreed goals
50
 
Equinor, Annual Report and Form 20-F 2021
 
Remuneration policy for international executives
Equinor is a broad global energy company, developing oil, gas, wind and solar energy in around 30 countries. The
company has high goals related to diversity and inclusion, and diversity at all levels including
 
among top management is
crucial in ensuring the long-term sustainable success of the company. From time to time the company will appoint
executives employed in international markets with different framework for executive base pay, variable pay and benefits,
than what is the case in the Norwegian market. To be able to hire international executives, the company needs to offer
competitive compensation in the markets where it operates. The policy of being competitive but not market leading
 
still
remains.
 
In order to ensure Equinor’s competitive position and attract talent in the international market,
 
the board of directors has
the mandate to exceed the levels for variable pay and pension terms described in the table
 
above, for remuneration of
executive vice presidents hired in the international market and the remuneration level will
 
reflect the at any time
prevailing and documented market level for the EVP position. The annual variable pay shall
 
not exceed 50% of base
salary at target (100% maximum) and the long-term incentive (LTI) annual grant shall be maximum 70% of base salary.
The threshold for variable pay and the company performance modifier as described below will apply. For the
international LTI a three years’ average company performance modifier will be applied. Pension contribution will be in
accordance with the local market, and the 12G cap on pension used in the Norwegian tax favored regime
 
is not
applicable for the international executives. Any decision on terms and conditions as described
 
above will be included in
the remuneration report subject to review and endorsement by the annual general meeting.
Duration of contracts with executive vice presidents
Duration of contracts with the executive vice presidents are not limited to a certain period and are valid
 
until the
executive resigns from the position or enters into a new position in the company.
Mobility
To support the company’s need for a mobile workforce also at the senior executive level, the company’s standard
international assignment framework can be used for candidates employed in a different country than the location
 
of the
CEC role. International assignment for a CEC position will normally be limited to a three-year period.
 
Localisation and relocation
If an executive is recruited to Equinor and employed on local terms and conditions different from the executive’s country
and market, the company may decide to cover reasonable relocation costs including housing and
 
schooling within the
international assignment framework for these elements for a period up to two years.
 
Threshold for variable pay and company performance modifier
The threshold and company performance modifier are implemented to strengthen the link between the
 
company’s
overall financial results and the individual variable pay.
Threshold
The threshold is implemented for affordability reasons to ensure that no or reduced variable pay would be granted
 
if the
company’s financial performance and position is weak and in a critical situation. The financial threshold is
 
applicable for
payment of annual variable pay and award of LTI grant.
The threshold has the following guiding parameters;
 
1) Cash flows provided by operating activities after tax and before working capital items
 
2) Net debt ratio and development
 
3) Company’s overall operational and financial performance.
“Green zone”
Cash flows provided by operating activities after tax and before working capital items higher
 
than USD 12 billion and a
net debt ratio below 30% will normally guide for no reduction of bonus.
“Yellow zone”
 
Cash flows provided by operating activities after tax and before working capital items lower
 
than USD 12 billion but
higher than USD 8 billion and a net debt ratio between 30% and 45% will normally guide
 
a reduction of bonus but not
annulment.
“Red zone”
 
Cash flows provided by operating activities after tax and before working capital items lower
 
than USD 8 billion and a net
debt ratio above 45% will normally guide no bonus.
Application of the threshold is subject to a discretionary assessment of the company’s overall performance
 
by the board
of directors. These measures and targets are indicative and will form part of a broader
 
assessment of bonus award. The
exhibit156p51i0
51
conclusion considers both achieved results and how these results are expected to impact the company’s
 
medium and
long-term development and value creation.
Company performance modifier
Based on approval by the annual general meeting in 2016, a company performance modifier was introduced
 
and has
been applied in the calculation of variable pay.
 
The company performance will be assessed against two equally weighted measures: relative total
 
shareholder return
(TSR) and relative return on average capital employed (ROACE). TSR and ROACE are currently
 
also applied as
performance indicators in the corporate performance management system.
 
The results of these two performance measures are compared to our peers and determine Equinor’s
 
relative position. A
position of Quartile 1 means that Equinor is amongst the top scoring quartile of peer companies.
 
A position of Quartile 4
means that Equinor is in the bottom performing quartile. In years with strong deliveries on relative
 
TSR and ROACE, the
matrix will result in the variable pay being modified with a factor higher than one and, correspondingly, lower than one in
weak years. The combination of ratings for both measures, will act as a ‘multiplier’
 
according to the guideline in the
matrix displayed below.
By applying relative numbers, the effect of fluctuating oil price will be reduced.
 
Within the framework of 50 - 150%, the matrix is a guideline and the multiplier (percentages)
 
may be adjusted if oil or
gas price effects or other occurrences outside the control of the company are deemed to cause
 
disproportionate results
in a given year. Application of the modifier is subject to discretionary assessment based on the company’s overall
performance.
The company performance modifier will be used in calculations of annual variable pay for members
 
of the corporate
executive committee. The modifier will also be applied in other variable pay schemes below the
 
corporate executive
level. Further application of the company performance modifier will also be assessed and
 
decided if deemed
appropriate.
The annual variable pay for members of the corporate executive committee employed by Equinor ASA
 
will be within a
framework of 45% of base salary, irrespective of the result of the modifier.
 
Pension and insurance schemes
 
Members of the corporate executive committee in Equinor ASA are covered by the company’s general occupational
pension scheme which is a defined contribution scheme with a contribution level of 7% below
 
7,1 G and 22% above 7,1
G. A defined benefit scheme is retained by a grandfathered group of employees. For new members
 
of the corporate
executive committee appointed after 13 February 2015, a cap on pension contribution at 12 G is
 
applied. In lieu of
pension accrual above 12 G a fixed salary addition of 18% is provided. This element does
 
not form basis of calculation
of AVP and LTI.
 
The 12 G cap is based on the Norwegian tax favoured occupational pension schemes
 
and will not be
applied to the pension schemes of executives employed outside Norway.
 
52
 
Equinor, Annual Report and Form 20-F 2021
 
Members of the corporate executive committee employed in Equinor ASA and appointed before 13 February
 
2015,
maintain their pension contribution above 12 G based on obligations in previously established agreements.
Pension terms that historically have been individually agreed with elements outside the framework
 
above will be
described in the annual remuneration report.
 
Equinor ASA has implemented a general cap on pensionable income at 12 G for all
 
new hires into the company
employed as of 1 September 2017.
In addition to the pension benefits outlined above, the executive vice presidents in the parent
 
company are offered
disability and dependents’ benefits in accordance with Equinor’s general pension
 
plan/defined benefit plan. Members of
the corporate executive committee are covered by the general insurance schemes applicable within
 
Equinor.
Severance pay arrangements
The chief executive officer and the executive vice presidents are entitled to a severance payment equivalent to
 
six
months’ salary, commencing after the six months’ notice period, when the resignation is requested by the company. The
same amount of severance payment is also payable if the parties agree that the employment should
 
be discontinued,
and the individual gives notice pursuant to a written agreement with the company. Any other payment earned by the
individual during the period of severance payment will be fully deducted. This relates to earnings
 
from any employment
or business activity where the individual has active ownership.
The entitlement to severance payment is conditional on the chief executive officer or the executive vice president
 
not
being guilty of gross misconduct, gross negligence, disloyalty or other material breach
 
of his/her duties.
The chief executive officer’s/executive vice president’s own notice will not instigate any severance payment.
Release of earned LTI grants and bonus shares at end of employment
 
If termination of employment is based on a mutual agreement between the executive and
 
Equinor, the company may
decide to release locked in LTI shares and award already earned bonus shares in the share savings scheme at the end
of employment.
Salary and employment conditions of other employees
Salary and employment conditions of employees of the company have been taken into account
 
when establishing the
remuneration policy. The remuneration and employment framework for the members of the executive committee are
based on the same main principles as applicable for the remuneration frameworks for senior
 
leaders in the company in
general.
Recruitment policy
From time to time, Equinor may recruit executives from outside of the organisation. Our
 
principles are designed to
attract and retain the right individuals to ensure the successful implementation of
 
our strategy and to safeguard our
long-term interests.
 
If an individual forfeits remuneration as a result of recruitment to Equinor, the company can compensate partly or fully
for the documented financial loss of unvested short and long-term incentive opportunity held by
 
preferred external
candidates. Such decision will take into consideration the vehicle, expected value and timing
 
of forfeited awards. Any
buy-out will be limited to one year’s base salary and normally paid over a period
 
of 24 months.
 
 
 
 
4867-8232-6291 v.1.1
LIST OF GUARANTOR SUBSIDIARIES
Equinor Energy AS, a company existing under the Norwegian Private Limited
Liability Companies Act and a wholly owned subsidiary of Equinor ASA, has
guaranteed or is a co-obligor for the following unsecured debt securities.
●
 
USD 300,000,000 7.75% Debentures due 2023
●
 
USD 900,000,000 2.650% Notes due 2024
●
 
USD 1,000,000,000 3.700% Notes due 2024
●
 
USD 500,000,000 3.250% Notes due 2024
●
 
USD 250,000,000 7.15% Debentures due 2025
●
 
USD 1,250,000,000 2.875% Notes due 2025
●
 
USD 750,000,000 1.750% Notes due 2026
●
 
USD 480,512,000 7.250% Debentures due 2027
●
 
USD 15,588,000 7.250% Debentures due 2027
●
 
USD 500,000,000 3.000% Notes due 2027
●
 
USD 1,000,000,000 3.625% Notes due 2028
●
 
USD 250,000,000 6.800% Debentures due 2028
●
 
USD 275,000,000 7.150% Debentures due 2029
●
 
USD 1,500,000,000 3.125% Notes due 2030
●
 
USD 750,000,000 2.375% Notes due 2030
●
 
USD 750,000,000 5.100% Notes due 2040
●
 
USD 500,000,000 3.625% Notes due 2040
●
 
USD 350,000,000 4.250% Notes due 2041
●
 
USD 300,000,000 4.250% Notes due 2041
●
 
USD 850,000,000 3.950% Notes due 2043
●
 
USD 750,000,000 4.800% Notes due 2043
●
 
USD 1,000,000,000 3.250% Notes due 2049
●
 
USD 1,250,000,000 3.700% Notes due 2050