Equibles

40-F

VERMILION ENERGY INC. (VET)

40-F 2023-03-09 For: 2022-12-31
View Original
Added on April 12, 2026

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

Form 40-F

◻ Registration statement pursuant to Section 12 of the Securities Exchange Act of 1934; or

þ Annual report pursuant to Section 13(a) or 15(d) of the Securities Exchange Act of 1934

For the fiscal year ended: December 31, 2022

Commission file number: No. 001-35829

Vermilion Energy Inc.

(Exact name of registrant as specified in its charter)

Alberta

(Province or other jurisdiction of incorporation or organization)

1311

(Primary standard industrial classification code number)

N/A

(I.R.S. employer identification number)

3500, 520 - 3rd Avenue S.W.

Calgary , Alberta **** T2P 0R3 Canada

( 403 ) 269-4884

(Address and telephone number of registrant’s principal executive office)

National Corporate Research, Ltd .

225 West 34th Street, Suite 910

New York , New York **** 10122 U.S.A.

( 212 ) 947-7200

(Name, address and telephone number of agent for service in the United States)

Securities registered pursuant to Section 12(b) of the Act:

Title of each class: Trading Symbol: Name of each exchange on which registered:
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Common Shares VET New York Stock Exchange

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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

For annual reports, indicate by check mark the information filed with this form:

þ Annual Information Form þ Audited Annual Financial Statements

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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: **** 163,226,618 shares

Indicate by check mark whether the Registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Exchange Act 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.

Yes þ No ◻

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Indicate by check mark whether the registrant has submitted electronically every 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 such files).

Yes þ No ◻

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Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 12b-2 of the Exchange Act.

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. 7262(b)) by the registered public accounting firm that prepared or issued its audit report.      þ

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).    ◻

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DOCUMENTS FILED PURSUANT TO GENERAL INSTRUCTIONS

In accordance with General Instruction B.(3) of Form 40-F, the Registrant has filed the following documents as part of this Annual Report on Form 40-F, as set forth in the Exhibit Index attached hereto:

Exhibit 99.1 - Annual Information Form for the fiscal year ended December 31, 2022

Exhibit 99.2 - Management’s Discussion and Analysis for the fiscal year ended December 31, 2022; and

Exhibit 99.3 - Audited Annual Financial Statements for the fiscal year ended December 31, 2022

In accordance with General Instruction D.(9) of Form 40-F, the Registrant has filed the written consent of certain experts named in the foregoing Exhibits as Exhibit 99.5 and the written consent of its Independent Registered Public Accounting Firm as Exhibit 99.4, as set forth in the Exhibit Index attached hereto.

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DISCLOSURE CONTROLS AND PROCEDURES

A. Evaluation of Disclosure Controls and Procedures

Vermilion Energy Inc. (the "Registrant") maintains disclosure controls and procedures designed to ensure that information required to be disclosed in the Registrant's filings under the Securities Exchange Act of 1934, as amended (the "Exchange Act") is recorded, processed, summarized and reported within the time period specified in the rules and forms of the Securities and Exchange Commission (the "Commission"). Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed by the Registrant in the reports that it files or submits under the Exchange Act is accumulated and communicated to the issuer's management, including its principal executive and principal financial officers, or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure. The Registrant's Chief Executive Officer, and Chief Financial Officer, after having evaluated the effectiveness of the Registrant's disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) as of the end of the period covered by this report have concluded that, as of such date, the Registrant's disclosure controls and procedures are effective.

It should be noted that while the Registrant’s Chief Executive Officer and the Chief Financial Officer believe that the Registrant’s disclosure controls and procedures provide a reasonable level of assurance that they are effective, they do not expect that the Registrant’s disclosure controls and procedures will prevent all errors and fraud. A control system, no matter how well conceived or operated, can provide only reasonable, not absolute, assurance that the objectives of the control system are met.

B. Management’s Annual Report on Internal Control Over Financial Reporting

See page 4 of the 2022 Audited Consolidated Financial Statements included as Exhibit 99.3 to this report.

C. Auditor Attestation

See page 6 of the 2022 Audited Consolidated Financial Statements included as Exhibit 99.3 to this report.

D. Changes in Internal Control Over Financial Reporting

There was no change in the Registrant's internal control over financial reporting that occurred during the period covered by this report that has materially affected, or is reasonably likely to materially affect, its internal control over financial reporting.

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NOTICES REQUIRED BY RULE 104 OF REGULATION BTR

None

AUDIT COMMITTEE FINANCIAL EXPERT

The Registrant's Board of Directors has determined that it has at least one audit committee financial expert (as such term is defined in the rules and regulations of the Commission) serving on its Audit Committee. Manjit Sharma has been determined to be such audit committee financial expert and is independent (as such term is defined by the New York Stock Exchange's corporate governance standards).

The Commission has indicated that the designation of Manjit Sharma as an audit committee financial expert does not make him an "expert" for any purpose, impose on his any duties, obligations or liability that are greater than the duties, obligations or liability imposed on him as a member of the Audit Committee and the Board of Directors in absence of such designation, or affect the duties, obligations or liability of any other member of the Audit Committee or Board of Directors. ​

CODE OF ETHICS

The Registrant has adopted a written “code of ethics” (as that term is defined in Form 40-F) that applies to its directors, officers and employees, including its principal executive officer, principal financial officer, principal accounting officer or controller, and persons performing similar functions. A copy of such code of ethics is available upon request or on the Registrant’s website at https://www.vermilionenergy.com/about-us/governance/. In 2022, there were no amendments to the code of ethics or waivers, including implicit waivers, from any provisions of the code of ethics.

PRINCIPAL ACCOUNTANT FEES AND SERVICES

Information about aggregate fees billed to us by our principal accountant, Deloitte LLP (PCAOB ID No. 1208) will be presented under the caption “Audit Committee Matters - External audit service fees” on page 54 of the Annual Information Form for the year ended December 31, 2022 included as Exhibit 99.1 to this report.

The Audit Committee pre-approves all audit related fees. The auditors present the estimate for the annual audit related services to the Audit Committee for approval prior to undertaking the annual audit of the financial statements.

All non-audit fees were pre-approved by the Audit Committee and none were approved on the basis of the de minimis exemption set forth in Rule 2-01(c)(7)(i)(C) of Regulation S-X.

OFF-BALANCE SHEET ARRANGEMENTS

The Registrant does not have any commitments or obligations, including contingent obligations, arising from arrangements with unconsolidated entities or persons (which are not otherwise discussed in the Registrant's Management’s Discussion and Analysis for the fiscal year ended December 31, 2022, filed as Exhibit 99.2 to this annual report on Form 40-F), that have or are reasonably likely to have a material current or future effect on its financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, cash requirements or capital resources.

DISCLOSURE OF CONTRACTUAL OBLIGATIONS

The required disclosure is included under the heading “Contractual Obligations and Commitments” in the Registrant’s Management’s Discussion and Analysis for the fiscal year ended December 31, 2022, filed as Exhibit 99.2 to this annual report on Form 40-F.

IDENTIFICATION OF THE AUDIT COMMITTEE

The Registrant’s Board of Directors has a separately designated standing Audit Committee established in accordance with Section 3(a)(58)(A) of the Exchange Act which satisfies the requirements of Exchange Act Rule 10A-3. The Registrant’s Audit Committee is comprised of Manjit Sharma (Chair), Robert Michaleski, Stephen Larke, and Judy Steele, all of whom, in the opinion of the Registrant’s Board of Directors are independent (as determined under Rule 10A-3 of the Exchange Act and the corporate governance standards of the NYSE) and are financially literate. Please refer to the Registrant's Annual Information Form attached as Exhibit 99.1 to this annual report on Form 40-F for details in connection with each of these members and their qualifications.

The members of the Audit Committee do not have fixed terms and are appointed from time to time by resolution of the directors.

The Audit Committee meets with the Registrant's Chief Executive Officer, Chief Financial Officer and the Registrant's independent auditors to review and inquire into matters affecting financial reporting, the system of internal accounting and financial controls, as well as audit procedures and audit plans. The Audit Committee also recommends to the Board of Directors which independent registered public auditing firm should be appointed by the Registrant, and reviews and recommends to the Board of Directors for approval the Registrant’s audited annual financial statements and accompanying management’s discussion and analysis.

The full text of the Audit Committee Terms of Reference is disclosed in the Registrant's Annual Information Form, attached hereto as Exhibit 99.1, and is incorporated by reference in this annual report on Form 40-F.

NYSE STATEMENT OF GOVERNANCE DIFFERENCES

As a Canadian corporation with securities listed on the Toronto Stock Exchange (“TSX”) and the New York Stock Exchange (“NYSE”), the Registrant is required to comply with all applicable Canadian requirements adopted by the Canadian Securities Administrators and the TSX, and applicable rules for foreign private issuers adopted by the Commission which give effect to the provisions of the Sarbanes-Oxley Act of 2002 (“Sarbanes-Oxley”). ​

The Registrant’s corporate governance practices meet or exceed all applicable Canadian and Sarbanes-Oxley requirements and also incorporate many “best practices” derived from those required to be followed by U.S. domestic companies under the NYSE listing standards. In accordance with Section 303A.11 of the NYSE Listed Company Manual, the Registrant has prepared a summary of the significant ways in which its corporate governance practices differ from those required to be followed by U.S. domestic companies under the NYSE’s corporate governance standards, which is accessible on the Registrant’s website at https://www.vermilionenergy.com/about-us/governance/.

DISCLOSURE PURSUANT TO SECTION 13(r) OF THE EXCHANGE ACT

In accordance with Section 13(r) of the Exchange Act, the Registrant is required to include certain disclosures in its periodic reports if it or any of its affiliates knowingly engaged in certain specified activities during the period covered by the report. Neither the Registrant nor its affiliates have knowingly engaged in any transaction or dealing reportable under Section 13(r) of the Exchange Act during the year ended December 31, 2022.

UNDERTAKING AND CONSENT TO SERVICE OF PROCESS

A. Undertaking

The Registrant undertakes to make available, in person or by telephone, representatives to respond to inquiries made by the Commission staff and to furnish promptly, when requested to do so by the Commission staff, information relating to: the securities registered pursuant to Form 40-F; the securities in relation to which the obligation to file an annual report on Form 40-F arises; or transactions in said securities.

B. Consent to Service of Process

The Registrant has previously filed with the Commission a Form F-X in connection with the class of securities in relation to which the obligation to file this report arises.

Any change to the name or address of the Registrant’s agent for service shall be communicated promptly to the Commission by amendment to Form F-X referencing the file number of the Registrant.

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SIGNATURES

Pursuant to the requirements of the Exchange Act, the Registrant certifies that it meets all of the requirements for filing on Form 40-F and has duly caused this annual report to be signed on its behalf by the undersigned, thereto duly authorized.

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​ VERMILION ENERGY INC (the Registrant)
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Date: March 8, 2023 ​ By: /s/ (“Lars Glemser”)
​ ​ Lars Glemser
​ ​ Vice President and Chief Financial Officer

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EXHIBIT INDEX

The following exhibits have been filed as part of this annual report:

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Exhibits **** Description
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99.1 ​ Annual Information Form for the Year Ended December 31, 2022
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99.2 ​ Management's Discussion and Analysis from the 2022 Annual Report to Shareholders
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99.3 ​ Audited Annual Financial Statements for the Year Ended December 31, 2022
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99.4 ​ Consent of Independent Registered Public Accounting Firm
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99.5 ​ Consent of Independent Petroleum Consultants
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99.6 ​ Officers’ Certifications of the Chief Executive Officer and Chief Financial Officer pursuant to Rule 13a-14(a) or Rule 15d-14(a) of the Securities Exchange Act of 1934
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99.7 ​ Certifications of the Chief Executive Officer and Chief Financial Officer pursuant to Rule 13a-14(b) or Rule 15d-14(b) of the Securities Exchange Act of 1934 and Section 1350 of Chapter 63 of Title 18 of the United States Code
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101 ​ Interactive Data File (formatted as Inline XBRL)
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104 ​ Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)

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Exhibit 99.1

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Table of Contents

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Glossary, Conventions, Abbreviations, and Conversions 2
Special Note Regarding Forward Looking Information 4
Presentation of Oil and Gas Information 6
Non-GAAP Measures 6
Vermilion's Organizational Structure 7
Description of the Business 7
General Development of the Business 11
Statement of Reserves Data and Other Oil and Gas Information 13
Directors and Officers 48
Description of Capital Structure 51
Market for Securities 53
Audit Committee Matters 53
Conflicts of Interest 55
Interest of Management and Others in Material Transactions 55
Legal Proceedings 55
Material Contracts 55
Interests of Experts 55
Transfer Agent and Registrar 55
Risk Factors 55
Additional Information 63
Appendix A ​
Report on reserves data by Independent Qualified Reserves Evaluator or Auditor (Form 51-101F2) 64
Appendix B ​
Report of Management and Directors on reserves data and other information (Form 51-101F3) 65
Appendix C ​
Audit Committee Mandate 66

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Glossary

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In addition to terms defined elsewhere in this annual information form, the following are defined terms used in this annual information form:

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“ABCA” means the Business Corporations Act(Alberta), R.S.A. 2000, c. B-9, as amended, including the regulations promulgated thereunder.

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“AIF” means this Annual Information Form and the appendices attached hereto.

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“Affiliate” when used to indicate a relationship with a person or company, has the same meaning as set forth in the Securities Act (Alberta).

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“Common Shares” means a common share in the capital of the Company.

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“Conversion Arrangement” means the plan of arrangement effected on September 1, 2010 under section 193 of the ABCA pursuant to which the Trust converted from an income trust to a corporate structure, and Unitholders exchanged their Trust Units for common shares of the Company on a one-for-one basis and holders of exchangeable shares of Vermilion Resources Ltd., previously a subsidiary of the company ("VRL"), received 1.89344 common shares for each exchangeable share held.

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“Dividend” means a dividend paid by Vermilion in respect of the common shares, expressed as an amount per common share.

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“GLJ” means GLJ Petroleum Consultants Ltd., independent petroleum engineering consultants of Calgary, Alberta.

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“GLJ Report” means the independent engineering reserves evaluation of certain oil, NGL and natural gas interests of the Company prepared by GLJ dated February 14, 2023 and effective December 31, 2022.

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“NCIB” means the normal course issuer bid approved by the Toronto Stock Exchange allowing Vermilion to repurchase its common shares.

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“Shareholders” means holders from time to time of the Company’s common shares.

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“Subsidiary” means, in relation to any person, any corporate, partnership, joint venture, association or other entity of which more than 50% of the total voting power of common shares or units of ownership or beneficial interest entitled to vote in the election of directors (or members of a comparable governing body) is owned or controlled, directly or indirectly, by such person.

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“Trust” means Vermilion Energy Trust, an unincorporated open-ended investment trust governed by the laws of the Province of Alberta that was dissolved and ceased to exist pursuant to the Conversion Arrangement.

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“Trust Unit” means units in the capital of the Trust.

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“Unitholders” means former unitholders of the Trust.

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“Vermilion” or the “Company” means Vermilion Energy Inc. and where context allows, its consolidated business enterprise, except that a reference to “Vermilion” prior to the date of the Conversion Arrangement means the consolidated business enterprise of the Trust, unless otherwise indicated.

​ Vermilion Energy Inc. ■ Page 2 ■ 2022 Annual Information Form

Conventions

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Unless otherwise indicated, references herein to "$" or "dollars" are to Canadian dollars.

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Production numbers stated refer to Vermilion's working interest share before deduction of crown, freehold, and other royalties. Reserve amounts are gross reserves, stated before deduction of royalties, as at December 31, 2022, based on forecast costs and price assumptions as evaluated in the GLJ Report.

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Abbreviations

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$M thousand dollars
$MM million dollars
°API an indication of the specific gravity of crude oil measured on the API (American Petroleum Institute) gravity scale
AECO the daily average benchmark price for natural gas at the AECO ‘C’ hub in southeast Alberta
bbl(s) barrel(s)
bbls/d barrels per day
boe barrel of oil equivalent, including: crude oil, condensate, natural gas liquids, and natural gas (converted on the basis of one boe for six mcf of natural gas)
mbbl thousand barrels
mboe thousand barrels of oil equivalent
mcf thousand cubic feet
mcf/d thousand cubic feet per day
mmboe million barrels of oil equivalent
mmbtu million British Thermal Units
mmcf million cubic feet
mmcf/d million cubic feet per day
NBP the reference price paid for natural gas in the United Kingdom at the National Balancing Point Virtual Trading Point operated by National Grid
NCIB normal course issuer bid
TTF the day-ahead price for natural gas at the Title Transfer Facility Virtual Trading Point operated by Dutch TSO Gas Transport Services
WTI West Texas Intermediate, the reference price paid in U.S. dollars at Cushing, Oklahoma for crude oil of standard grade

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Conversions

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The following table sets forth certain standard conversions from Standard Imperial Units to the International System of Units (or metric units):

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To Convert From To Multiply By
mcf Cubic metres 28.174
Cubic metres Cubic feet 35.494
bbls Cubic metres 0.159
Cubic metres bbls oil 6.290
Feet Metres 0.305
Metres Feet 3.281
Miles Kilometres 1.609
Kilometres Miles 0.621
Acres Hectares 0.405
Hectares Acres 2.471

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​ Vermilion Energy Inc. ■ Page 3 ■ 2022 Annual Information Form

Special Note Regarding Forward Looking Statements

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Certain statements included or incorporated by reference in this annual information form may constitute forward looking statements or information under applicable securities legislation. Such forward looking statements or information typically contain statements with words such as "anticipate", "believe", "expect", "plan", "intend", "estimate", "propose", or similar words suggesting future outcomes or statements regarding an outlook. Forward looking statements or information in this annual information form may include, but are not limited to:

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● capital expenditures;
● return of capital;
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● business strategies and objectives;
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● estimated reserve quantities and the discounted present value of future net cash flows from such reserves;
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● petroleum and natural gas sales;
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● future production levels (including the timing thereof) and rates of average annual production growth;
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● exploration and development plans;
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● acquisition and disposition plans and the timing thereof;
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● operating and other expenses, including the payment of future dividends;
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● royalty, income tax and inflation rates; and
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● the timing of regulatory proceedings and approvals.
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Such forward-looking statements or information are based on a number of assumptions of which all or any may prove to be incorrect. In addition to any other assumptions identified in this document, assumptions have been made regarding, among other things:

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● the ability of the Company to obtain equipment, services and supplies in a timely manner to carry out its activities in Canada and internationally;
● the ability of the Company to market crude oil, natural gas liquids and natural gas successfully to current and new customers;
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● the timing and costs of pipeline and storage facility construction and expansion and the ability to secure adequate product transportation;
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● the timely receipt of required regulatory approvals;
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● the ability of the Company to obtain financing on acceptable terms;
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● foreign currency exchange rates and interest and inflation rates;
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● future crude oil, natural gas liquids and natural gas prices; and
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● Management’s expectations relating to the timing and results of development activities.
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Although the Company believes that the expectations reflected in such forward looking statements or information are reasonable, undue reliance should not be placed on forward looking statements because the Company can give no assurance that such expectations will prove to be correct. Financial outlooks are provided for the purpose of understanding the Company’s financial strength and business objectives and the information may not be appropriate for other purposes. Forward looking statements or information are based on current expectations, estimates and projections that involve a number of risks and uncertainties which could cause actual results to differ materially from those anticipated by the Company and described in the forward looking statements or information. These risks and uncertainties include but are not limited to:

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● the ability of management to execute its business plan;
● the risks of the oil and gas industry, both domestically and internationally, such as operational risks in exploring for, developing and producing crude oil, natural gas liquids and natural gas;
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● risks and uncertainties involving geology of crude oil, natural gas liquids and natural gas deposits;
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● risks inherent in the Company's marketing operations, including credit risk;
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● the uncertainty of reserves estimates and reserves life and associated expenditures;
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● the uncertainty of estimates and projections relating to production, costs and expenses;
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● potential delays or changes in plans with respect to exploration or development projects or capital expenditures;
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● the Company's ability to enter into or renew leases on acceptable terms;
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● fluctuations in crude oil, natural gas liquids and natural gas prices, foreign currency exchange rates and interest and inflation rates;
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● health, safety and environmental risks;
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● uncertainties as to the availability and cost of financing;
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● the ability of the Company to add production and reserves through exploration and development activities;
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● general economic and business conditions;
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● the possibility that government policies or laws may change or governmental approvals may be delayed or withheld;
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● uncertainty in amounts and timing of royalty payments;
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● risks associated with existing and potential future law suits and regulatory actions against or involving the Company; and
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Vermilion Energy Inc. ■ Page 4 ■ 2022 Annual Information Form

● other risks and uncertainties described elsewhere in this annual information form or in the Company's other filings with Canadian securities authorities.

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The forward-looking statements or information contained in this annual information form are made as of the date hereof and the Company undertakes no obligation to update publicly or revise any forward-looking statements or information, whether as a result of new information, future events or otherwise, unless required by applicable securities laws.

​ Vermilion Energy Inc. ■ Page 5 ■ 2022 Annual Information Form

Presentation of Oil and Gas Information

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Oil and gas reserves and production

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All oil and natural gas reserve information contained in this annual information form is derived from the GLJ Report and has been prepared and presented in accordance with the Canadian Oil and Gas Evaluation Handbook (“COGEH”) and National Instrument 51-101 Standards of Disclosure for Oil and Gas Activities ("NI 51-101"). The actual oil and natural gas reserves and future production will be greater than or less than the estimates provided in this annual information form. The estimated future net revenue from the production of the disclosed oil and natural gas reserves does not represent the fair market value of these reserves.

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Under NI 51-01, disclosure of production volumes should include segmentation by product type as defined in the instrument. In this report, references to "crude oil" and "light and medium crude oil" mean "light crude oil and medium crude oil" and references to "natural gas" mean "conventional natural gas".

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Natural gas volumes have been converted on the basis of six thousand cubic feet of natural gas to one barrel of oil equivalent. Barrels of oil equivalent (“boe”) may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead.

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Additional Non-GAAP and Other Financial Measures

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This AIF includes references to certain financial and performance measures which do not have standardized meanings prescribed by International Financial Reporting Standards ("IFRS") and therefore may not be comparable to similar measures disclosed by other issuer. These measures include:

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● Fund flows from operations: Fund flows from operations is a total of segments measure comparable to net earnings and is comprised of sales less royalties, transportation, operating, G&A, corporate income tax, PRRT, windfall taxes, interest expense, and realized loss on derivatives, add realized gain on foreign exchange and realized other income. Information is included in this document by reference, more information and a reconciliation to primary financial statement measures can be found within the "Consolidated Financial Performance Review" section of the December 31, 2022 MD&A available on SEDAR at www.sedar.com.
● Operating Netbacks: Operating Netbacks is a non-GAAP financial measure most directly comparable to GAAP measure net earnings and is calculated as sales less royalties, operating expense, transportation costs, PRRT, and realized hedging gains and losses presented on a per unit basis.  Information is included in this document by reference, more information and a reconciliation to primary financial statement measures can be found within the "Supplemental Table 1: Netbacks" section of the December 31, 2022 MD&A available on SEDAR at www.sedar.com.
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In addition, this AIF includes references to certain financial measures which are not specified, defined, or determined under IFRS and are therefore considered non-GAAP financial measures. These non-GAAP financial measures are unlikely to be comparable to similar financial measures presented by other issuers. These non-GAAP financial measures include:

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● Cash dividends per share: Represents actual cash dividends paid per share by the Company during the relevant periods. Information is included in this document by reference, more information can be found within the "Non-GAAP Financial Measures" section of the December 31, 2022 MD&A available on SEDAR at www.sedar.com.
● Capital expenditures: Represents the sum of drilling and development and exploration and evaluation. Information is included in this document by reference, more information and a reconciliation to primary financial statement measures can be found within the "Non-GAAP Financial Measures" section of the December 31, 2022 MD&A available on SEDAR at www.sedar.com.
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​ Vermilion Energy Inc. ■ Page 6 ■ 2022 Annual Information Form

Vermilion's Organizational Structure

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Vermilion Energy Inc. is the successor to the Trust, following the completion of the Conversion Arrangement whereby the Trust converted from an income trust to a corporate structure by way of a court approved plan of arrangement under the ABCA on September 1, 2010.

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As at December 31, 2022, Vermilion had 740 full time employees of which 236 employees were located in its Calgary head office, 127 employees in its Canadian field offices, 126 employees in France, 67 employees in the Netherlands, 35 employees in Australia, 24 employees in the United States, 34 employees in Germany, 6 employees in Hungary, 7 employees in Croatia and 78 employees in Ireland.

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Vermilion was incorporated on July 21, 2010 pursuant to the provisions of the ABCA for the purpose of facilitating the Conversion Arrangement. The registered and head office of Vermilion Energy Inc. is located at Suite 3500, 520 – 3rd Avenue S.W., Calgary, Alberta, T2P 0R3.

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The following is a list of the Company's material subsidiaries and where each material subsidiary was incorporated or formed. The Company holds 100% of the votes attaching to all voting securities of each material subsidiary beneficially owned directly or indirectly by Vermilion.

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● Vermilion Oil & Gas Australia Pty Ltd. (Australia)
● Vermilion Energy Canada Ltd. (Alberta)
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● Vermilion Energy Germany GmbH & Co. KG (Germany)
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● Vermilion Energy Ireland Limited (Ireland)
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● Vermilion Energy Netherlands B.V. (Netherlands)
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● Vermilion Energy USA LLC (United States)
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● Vermilion Exploration and Production Ireland Limited (Ireland)
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● Vermilion Exploration SAS (France)
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● Vermilion Hungary Southern Battonya Concession Kft. (Hungary)
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● Vermilion Moraine SAS (France)
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● Vermilion Pyrénées SAS (France)
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● Vermilion Rep SAS (France)
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● Vermilion Resources (Alberta)
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● Vermilion Slovakia Exploration s.r.o. (Slovakia)
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● Vermilion Zagreb Exploration d.o.o. (Croatia)
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● Leucrotta Exploration Inc. (Alberta)
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Description of the Business

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Vermilion is an international energy producer that seeks to create value through the acquisition, exploration, development and optimization of producing assets in North America, Europe and Australia. Our business model emphasizes free cash flow generation and returning capital to investors when economically warranted, augmented by value-adding acquisitions. Vermilion's operations are focused on the exploitation of light oil and liquids-rich natural gas conventional and unconventional resource plays in North America and the exploration and development of conventional natural gas and oil opportunities in Europe and Australia.

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Vermilion's priorities are health and safety, the environment, and profitability, in that order. Nothing is more important to us than the safety of the public and those who work with us, and the protection of our natural surroundings.  We have been recognized by leading ESG rating agencies for our transparency on, and management of, key environmental, social and governance issues. In addition, we emphasize strategic community investment in each of our operating areas.

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Vermilion has operations in two geographic regions: North America and International. Vermilion's business within these regions is managed at the country level through business units which form the basis of the Company's operating segments. These business units and the material crude oil and natural gas properties, facilities and installations in which Vermilion has an interest are discussed below. Vermilion Energy Inc. ■ Page 7 ■ 2022 Annual Information Form

The following table summarizes production, sales, proved reserves, and proved plus probable reserves for each of Vermilion's business units as at and for the year ended December 31, 2022:

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​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ **** ​ **** ​ **** ​ **** ​ **** ​ **** ​ **** Gross Proved
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Gross Proved ​ Plus Probable
​ ​ Production ​ Oil sales ​ NGL sales ​ Natural gas sales ​ Sales ​ Reserves ​ Reserves
Business Unit ​ (boe/d) ​ ($ millions) ​ ($ millions) ​ ($ millions) ​ ($ millions) ​ (mboe)^(1)^ ​ (mboe)^(1)^
Canada ​ 52,364 ​ 910,863 ​ 114,128 ​ 319,293 ​ 1,344,284 ​ 210,335 ​ 348,800
France ​ 7,639 ​ 365,431 ​ — ​ — ​ 365,431 ​ 29,528 ​ 38,954
Netherlands 5,510 2,119 — 560,738 562,857 5,844 13,143
Germany 5,798 62,464 — 418,796 481,260 18,300 32,688
Ireland 4,579 15 — 324,330 324,345 6,728 10,871
Australia 3,995 221,187 — — 221,187 6,403 12,531
United States 5,207 130,150 19,385 16,698 166,233 34,335 63,244
Central and Eastern Europe 95 — — 10,797 10,797 1,658 2,557
Total 85,187 1,692,229 133,513 1,650,652 3,476,394 313,129 522,790
North America 57,571 1,041,013 133,513 335,991 1,510,517 244,670 412,045
International 27,616 651,216 — 1,314,661 1,965,877 68,459 110,745
(1) "Gross Reserves" are Vermilion's working interest (operating or non-operating) share before deduction of royalty obligations and without including any royalty interests of Vermilion.
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Canada Business Unit

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Vermilion’s Canadian operations are primarily focused in the West Pembina region of West Central Alberta, in southeast Saskatchewan and Manitoba, and in the Mica property straddling the Alberta and British Columbia borders. In West Pembina, the Company targets condensate-rich Mannville natural gas and Cardium light oil, while in southeast Saskatchewan and Manitoba the Company targets light oil in the Mississippian Midale, Frobisher/Alida and Ratcliffe formations. At Mica, the Company targets tight oil and shale gas in the Montney formation. West Pembina is the Company's main natural gas liquids ("NGL") producing area.

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Vermilion holds an average 82% working interest in 796,648 (649,892 net) acres of developed land, and an average 85% working interest in 384,237 (325,777 net) acres of undeveloped land in Canada. Vermilion had 498 (356.5 net) producing conventional natural gas and shale gas wells and 3,005 (1,902.6 net) producing light and medium crude oil wells in Canada as at December 31, 2022.

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Vermilion has access to ample facilities and processing capacity across the major plays in its Canadian portfolio. In West Central Alberta, Vermilion's operations are concentrated in core areas where the Company owns and operates the large majority of associated key infrastructure including pipelines, compressor stations, oil batteries and gas plants, many of which have surplus capacity for future production. Furthermore, the Company is interconnected in several locations with third party midstream infrastructure that provides significant capacity for growth. In Saskatchewan, where operations are focused on light crude oil, Vermilion owns and operates an extensive network of pipelines and oil batteries that also have surplus capacity for future production. At Mica, the Company has infrastructure in place for current operations, with short-term growth plans currently being permitted for construction and a long-term development plan in place targeting production of 28,000 boe/d. The Company's high degree of operating control and access to key infrastructure across our Canadian properties allows Vermilion to drive operating efficiencies in the field while supporting future growth opportunities.

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During 2022, Vermilion drilled or participated in 65 (55.0 net) wells across our Canadian assets. In 2023, we plan to drill or participate in 22 (18.8 net) light crude oil wells in Saskatchewan, seven (6.1 net) natural gas liquids-rich conventional natural gas wells in Alberta, and seven (7.0 net) tight oil and shale gas wells in the Montney.

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United States Business Unit

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Vermilion entered the United States in 2014 through the acquisition of land and producing assets in the East Finn crude oil field in the Powder River Basin of northeastern Wyoming and expanded its position through acquisitions of mineral land and producing assets in the Hilight crude oil field, located approximately 40 miles northwest of the East Finn assets, in 2018 and 2021. The Company's assets include 149,043 (122,686 net) acres of land in the Powder River basin, of which 44% is undeveloped. Vermilion had 169 (161.8 net) producing light and medium crude oil wells in the United States as at December 31, 2022. The majority of our working interest ownership in Wyoming is Company operated.

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During 2022, Vermilion continued to focus on the Turner Sand development in the Powder River Basin, drilling eight (6.2 net) light and medium crude oil wells on its Hilight asset. In 2023, Vermilion expects to drill 16 (8.2 net) light and medium crude oil wells, including participating in light and medium crude oil wells targeting the Parkman and Niobrara formations. Vermilion Energy Inc. ■ Page 8 ■ 2022 Annual Information Form

France Business Unit

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Vermilion entered France in 1997 and completed three additional acquisitions in subsequent years. Vermilion is the largest oil producer in the country with approximately two-thirds of the domestic market share. The Company's oil is priced with reference to Dated Brent.

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Vermilion's main producing areas in France are located in the Aquitaine Basin which is located southwest of Bordeaux, France and in the Paris Basin, located just east of Paris. The two major fields in the Paris Basin area are Champotran and Chaunoy and the two major fields in the Aquitaine Basin are Parentis and Cazaux. Vermilion operates several oil batteries in the country and, given the legacy nature of these assets, the throughput capability of these batteries exceeds any projected future requirements. Vermilion holds an average 96% working interest in 258,125 (248,873 net) acres of developed land and an average 100% working interest in 106,993 (106,993 net) acres of undeveloped land in the Aquitaine and Paris Basins. Vermilion had 307 (301.0 net) producing light and medium crude oil wells in France as at December 31, 2022.

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In 2023, Vermilion intends to continue its ongoing program of workovers and well optimizations. Vermilion seeks to maintain its French production by mitigating declines through workovers and optimizations.

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Netherlands Business Unit

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Vermilion entered the Netherlands in 2004 and is the second largest onshore operator in the country. Vermilion's natural gas production in the Netherlands is priced off of the TTF index.

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Vermilion's Netherlands assets consist of 28 onshore concessions (100% operated) and 17 offshore concessions (non-operated). Production consists primarily of natural gas with a small amount of associated natural gas liquids. Vermilion’s total land position in the Netherlands covers 1,604,206 (844,409 net) acres at an average 53% working interest, of which 90% is undeveloped. Vermilion had 99 (40.7 net) producing conventional natural gas wells as at December 31, 2022.

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During 2022, the Company drilled one (0.5 net) conventional natural gas well in the Netherlands. In 2023, Vermilion plans to drill two (1.0 net) conventional natural gas wells and expects that its inventory of potentially high-impact exploration and development opportunities in the Netherlands will maintain or moderately grow the Company's production base in the country.

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Germany Business Unit

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Vermilion entered Germany in 2014 through the acquisition of a 25% non-operated interest in natural gas producing assets. In December 2016, Vermilion completed an acquisition of crude oil and natural gas producing properties that provided Vermilion with its first operated position in the country. Vermilion holds a significant undeveloped land base in Germany as a result of an extensive farm-in agreement the Company entered into in 2015. In 2021, Vermilion completed two minor acquisitions, increasing the Company’s non-operated working interest in certain assets to 50%. Vermilion's natural gas production in Germany is priced off the THE index, which is highly correlated to the TTF benchmark, and Vermilion's light and medium crude oil production is priced with reference to Dated Brent.

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Vermilion’s producing assets in Germany consist of operated and non-operated interests in eleven natural gas fields and nine light and medium crude oil fields with extensive infrastructure in place. Vermilion had 70 (58.4 net) producing light and medium crude oil wells and 24 (13.4 net) producing conventional natural gas wells as at December 31, 2022.

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Vermilion's land position in northwest Germany is comprised of 107,351 (54,626 net) developed acres and 1,549,929 (706,817 net) undeveloped acres. In addition, the Company holds a 50% equity interest in Hannoversche Erdölleitung GmbH ("HEG"), a joint venture company created in 1959 that collects and transports crude oil through a 185 km network of infrastructure from the Hannover region to rail loading facilities in Hannover.

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During 2022, Vermilion drilled three (3.0 net) light and medium crude oil wells and continued to execute various well optimization and workover programs to preserve production. In 2023, Vermilion plans to drill three (2.3 net) wells, including two (2.0 net) light and medium crude oil wells and one (0.3 net) high-prospect conventional natural gas well.

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Ireland Business Unit

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Vermilion has a 20% operated interest in the offshore Corrib natural gas field and related processing facilities located off the northwest coast of Ireland. Vermilion initially acquired an 18.5% non-operated interest in 2009. In 2018, Vermilion entered into a strategic partnership with the Canadian Pension Plan Investment Board ("CPPIB"), as a result of which Vermilion acquired an additional 1.5% working interest and assumed operatorship of Corrib. Vermilion Energy Inc. ■ Page 9 ■ 2022 Annual Information Form

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Corrib first began natural gas production in late December 2015. Production volumes reached full plant capacity of approximately 350 mmcf/d (gross) at the end of 2016. Production plateaued at this level until decline started at the beginning of 2018. The Corrib field constitutes 100% of Ireland's domestic natural gas production.

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On November 29, 2021, Vermilion announced an agreement to acquire an incremental 36.5% working interest in Corrib from Equinor ASA,  increasing the Company's operated ownership to 56.5% and adding approximately 7,700 boe/d of production for total consideration of $556 million, before closing adjustments and contingent payment. The acquisition has an effective date of January 1, 2022, and is anticipated to close in 2023 after all requisite approvals have been received. During 2023, Vermilion plans to continue to focus on facility maintenance and optimization, including a plant turnaround and other non-routine maintenance.

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Central and Eastern Europe ("CEE") Business Unit

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Vermilion established its CEE business unit in 2014 with a head office in Budapest, Hungary. The CEE business unit is responsible for business development in the CEE, including managing the exploration and development opportunities associated with the Company's land holdings in Hungary, Slovakia and Croatia.

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Vermilion's land position in the CEE consists of 975,374 (975,374 net) acres in Croatia, 614,625 (614,625 net) acres in Hungary and 97,907 (48,954 net) acres in Slovakia. Currently, 99% of Vermilion's land position in the CEE is undeveloped. In 2022, the Company let certain non-prospective licenses in Hungary expire.

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During 2022, Vermilion drilled two (2.0 net) conventional natural gas wells in Croatia and three (3.0 net) conventional natural gas wells in Hungary, but none of these exploratory wells encountered commercial hydrocarbons. In Croatia, the Company also continued to advance the planning, design and regulatory work for the gas plant on the SA-10 block in preparation for the tie-in of two previously drilled conventional natural gas wells and executed its 3-D seismic program. In 2023, Vermilion plans to continue its exploratory drilling activity in CEE by drilling three (3.0 net) light and medium crude oil wells in Croatia, along with commissioning the SA-10 gas plant, including the tie-in of the two previously drilled conventional natural gas wells, in late-2023.

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Australia Business Unit

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Vermilion holds a 100% operated working interest in the Wandoo offshore crude oil field and related production facilities, located on Western Australia's northwest shelf. Vermilion acquired its interest over two acquisitions completed in 2005 and 2007. Production is sourced from 19 producing well-bores including five dual laterals that are tied into two platforms, Wandoo 'A' and Wandoo 'B'. Wandoo 'B' is permanently manned, houses the required production facilities and incorporates 400,000 bbls of crude oil storage within the platform's concrete gravity structure. The Wandoo 'B' facilities are capable of processing 208,000 bbl/d of total fluid to separate crude oil from produced water. Vermilion's land position in the Wandoo field is comprised of 59,552 acres (gross and net).

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In 2022, Vermilion drilled two (2.0 net) light and medium crude oil wells, and does not presently expect to drill any additional Australian wells over the next two years. The Company intends to manage its Australian production and related capital investment programs to achieve corporate targets while meeting long-term supply requirements of our customers.

​ Vermilion Energy Inc. ■ Page 10 ■ 2022 Annual Information Form

General Development of the Business

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Three Year History and Outlook

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The following describes the development of Vermilion's business over the last three completed financial years.

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2020

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Vermilion achieved annual production of 95,190 boe/d on total E&D capital investment of $367 million, which was reduced from the original budget of $450 million in response to the global economic slowdown induced by the COVID-19 pandemic.

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In early 2020, Vermilion suspended its monthly dividend and announced an $80 to $100 million reduction to its annual capital budget in response to the COVID-19 pandemic and the resulting negative impact on near-term oil demand and commodity prices.

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On May 25, 2020, Vermilion's Board of Directors appointed Lorenzo Donadeo as Executive Chairman and Curtis Hicks as President following the departure of Anthony Marino as President and Chief Executive Officer. Mr. Donadeo is one of the co-founders of Vermilion and served as Chairman of the Board since March 1, 2016. Previously, Mr. Donadeo was the Chief Executive Officer of Vermilion from 2003 to 2016. Mr. Hicks was previously the CFO of Vermilion from 2003 to 2018.

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In lieu of filling the role of Chief Executive Officer, Vermilion re-established an Executive Committee consisting of a minimum of five senior executives from within the Company with a mandate to review and approve key organizational, financial, operational and strategic decisions. The re-established Executive Committee included the Executive Chairman, President, Vice President and Chief Financial Officer, Vice President North America, Vice President International and HSE, Vice President European Operations and the Vice President Business Development.

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Vermilion continued to build on its track record of industry-leading ESG performance based on rankings by third party ratings agencies in 2020. Vermilion ranked at the top of its peer group in 2020 in the SAM Corporate Sustainability Assessment (“CSA”). The Company was also selected for The Sustainability Yearbook 2021, which recognizes that our CSA sustainability performance is within the top 15% of our industry (SAM's Upstream Oil & Gas and Integrated category). Vermilion received a rating of "AA" on a scale of AAA (leader) to CCC (laggard) in the MSCI ESG Ratings assessment, which reflects exposure to industry-specific ESG risks and the ability to manage those risks. Vermilion was named to the CDP Climate Leadership Level (A-) for the fourth consecutive year in 2020. Vermilion was one of five Canadian oil and gas companies, one of seven oil and gas companies in North America, and one of 20 oil and gas companies globally to achieve this level, ranking Vermilion in the top 10% of oil and gas companies globally. In November 2020, Vermilion released its 2020 Corporate Sustainability Report, marking the Company's 7th year of ESG reporting. The 2020 report highlights Vermilion's ongoing focus on reducing emissions within its operations, along with a content index that includes recommendations from the Task Force on Climate-related Financial Disclosures and the Sustainability Accounting Standards Board.

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2021

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Vermilion achieved annual production of 85,408 boe/d on total E&D capital investment of $375 million. E&D capital investment in 2021 was limited as the Company focused on preserving liquidity, maximizing free cash flow and reducing debt.

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During the third quarter of 2021, the Company completed a strategic acquisition which included 20,000 net acres of land adjacent to its Hilight field in Wyoming, with production of approximately 1,500 boe/d. Total consideration for the acquisition was US$76 million.

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On September 8, 2021, Vermilion appointed Dion Hatcher as President effective January 1, 2022, replacing Curtis Hicks as President (who remained with the Company as an advisor until April 1, 2022). At the time of his appointment, Mr. Hatcher had over 25 years of industry experience and had spent the last 15 years in a variety of leadership roles during his tenure at Vermilion, most recently in the role of Vice President, North America.

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On November 29, 2021, Vermilion announced an agreement to acquire an incremental 36.5% working interest in Corrib from Equinor ASA, increasing the Company's operated ownership to 56.5% and adding approximately 7,700 boe/d of production for total consideration of $556 million, before closing adjustments and contingent payment. The acquisition has an effective date of January 1, 2022, and is anticipated to close in 2023 after all requisite approvals have been received. This acquisition consolidates interest in a high margin, low decline and low emission asset, while increasing exposure to premium priced European natural gas and rebalances Vermilion's international weighting.

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Vermilion continued to deliver superior ESG performance based on rankings by third party rating agencies in 2021. Vermilion ranked at the top of its peer group in 2021 in the S&P Global Corporate Sustainability Assessment (“CSA”). The Company was also selected for The Sustainability Yearbook 2022, which recognizes that our CSA sustainability performance is within the top 15% of our industry (S&P Global’s Upstream Oil & Gas and Integrated category). Vermilion maintained its rating of "AA" on a scale of AAA (leader) to CCC (laggard) in the MSCI ESG Ratings assessment, which reflects Vermilion Energy Inc. ■ Page 11 ■ 2022 Annual Information Form

exposure to industry-specific ESG risks and the ability to manage those risks. Vermilion received a B in 2021 for both CDP Climate and CDP Water submissions, a combined performance that places it tied for the top decile of oil and gas companies globally. In August 2021, Vermilion released its 2021 Sustainability Report, marking the Company's 8th year of ESG reporting. Note that effective in 2022, Vermilion’s reporting in alignment with the Task Force on Climate-related Financial Disclosure relating to: Governance is located in our management proxy circular for our annual meeting of shareholders, and relating to Strategy, Risk Management, and Metrics and Targets in our annual MD&A. This information is also located in the Energy Transition section of our Sustainability Report, available online at www.vermilionenergy.com/sustainability.

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2022

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Vermilion achieved annual production of 85,187 boe/d on total E&D capital investment of $552 million. During the second quarter of 2022, the Company acquired all of the issued and outstanding securities of Leucrotta Exploration Inc. ("Leucrotta") for total consideration of $500 million. The primary asset acquired pursuant to the Leucrotta acquisition was the Mica property, comprised of 81,000 gross (77,000 net) contiguous acres of Montney mineral rights in the Peace River Arch straddling the Alberta and British Columbia borders. At the time of acquisition, we conservatively identified 275 multi-zone, extended reach, drilling prospects, representing an expected two decades or more of low-risk, self-funding, high-deliverability drilling inventory with strong rates of return.

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In March 2022, Vermilion reinstated a quarterly dividend of $0.06 per share, which was subsequently increased to $0.08 per share in August 2022. In July 2022, Vermilion received TSX approval for the NCIB, allowing the Company to purchase up to 16,076,666 common shares, representing approximately 10% of its public float as at June 22, 2022, over a twelve month period commencing on July 6, 2022. In 2022, Vermilion declared $46 million in dividends and repurchased 2.3 million shares pursuant to the NCIB for a total of $72 million.

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In April 2022, Vermilion issued US$400 million aggregate principal amount of eight-year senior unsecured notes bearing interest at a rate of 6.875% per annum, extended the maturity date of the Company's revolving credit facility to May 29, 2026 (from May 31, 2024), and reduced the total facility amount to Vermilion's targeted level of $1.6 billion (from $2.1 billion).

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Subsequent to year-end, we signed an agreement to sell certain assets in southeast Saskatchewan. The assets are comprised of approximately 5,500 boe/d of non-core light oil production spread across the greater Arcola and Queensdale areas of southeast Saskatchewan. Total cash consideration is $225 million, before closing adjustments. The transaction has an effective date of September 1, 2022 and is expected to close in March 2023.

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Vermilion's commitment to reducing the environmental impact of traditional energy production continued to be reflected in superior ESG performance based on rankings by third party rating agencies in 2022. Vermilion ranked top of our peer group in the S&P Global Corporate Sustainability Assessment (“CSA”). The Company improved its rating to "AAA" on a scale of AAA (leader) to CCC (laggard) in the MSCI ESG Ratings assessment, which reflects exposure to industry-specific ESG risks and the ability to manage those risks. Vermilion received an A- and a B for CDP Climate and CDP Water submissions, respectively. In July 2022, Vermilion released its 2022 Sustainability Report, marking the Company's 9th year of ESG reporting. Note that effective in 2022, Vermilion’s reporting aligned with the Task Force on Climate-related Financial Disclosure relating to Governance (located in our management proxy circular for our annual meeting of shareholders), and relating to Strategy, Risk Management, and Metrics and Targets (located in our annual MD&A). This information is also located in the Energy Transition section of our Sustainability Report, available online at www.vermilionenergy.com/sustainability.

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Outlook

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In January 2023, Vermilion announced an E&D capital budget for 2023 of $570 million with corresponding production guidance of 87,000 to 91,000 boe/d, assuming a March 31, 2023 closing of the Corrib acquisition. Taking into account the southeast Saskatchewan asset sale and unplanned downtime in Australia, production guidance was revised to 82,000 to 86,000 boe/d with the release of the Company’s annual report in March 2023.

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In conjunction with the 2023 budget release, the Company also announced its plan to increase the quarterly dividend to $0.10 per share in Q1 2023 and the resumption of share buybacks under the Company's NCIB. Vermilion's business model continues to allow for flexibility in response to volatile commodity prices and regulatory changes. The Company intends to fund future return of capital and E&D capital investment from internally generated cash flow from operating activities, while allocating a majority of free cash flow to debt reduction until we achieve our next target level of $1.0 billion of net debt, at which time we plan to increase the allocation of capital returned to shareholders.

​ Vermilion Energy Inc. ■ Page 12 ■ 2022 Annual Information Form

Statement of Reserves Data and Other Oil and Gas Information

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Reserves and future net revenue

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The following is a summary of the crude oil and natural gas reserves and the value of future net revenue of Vermilion as evaluated by GLJ in a report dated February 14, 2023 with an effective date of December 31, 2022. Pricing used in the forecast price evaluations is set forth in the notes to the tables.

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Reserves and other oil and gas information contained in this section is effective December 31, 2022 unless otherwise stated.

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All evaluations of future net revenue set forth in the tables below are stated after overriding and lessor royalties, Crown royalties, freehold royalties, mineral taxes, direct lifting costs, normal allocated overhead and future capital investments, including abandonment and reclamation obligations. Future net revenues estimated by the GLJ Report do not represent the fair market value of the reserves. Other assumptions relating to the costs, prices for future production and other matters are included in the GLJ Report. There is no assurance that the future price and cost assumptions used in the GLJ Report will prove accurate and variances could be material.

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Reserves are established using deterministic methodology. Total proved reserves are established at the 90 percent probability (P90) level. There is a 90 percent probability that the actual reserves recovered will be equal to or greater than the P90 reserves. Total proved plus probable reserves are established at the 50 percent probability (P50) level. There is a 50 percent probability that the actual reserves recovered will be equal to or greater than the P50 reserves.

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The Report on Reserves Data by Independent Qualified Reserves Evaluator or Auditor in Form 51-101F2 and the Report of Management and Directors on Oil and Gas Disclosure in Form 51-101F3 are contained in Schedules "A" and "B", respectively.

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The following tables provide reserves data and a breakdown of future net revenue by component and product type using forecast prices and costs. For Canada, the tables following include Alberta Gas Cost Allowance.

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​ Vermilion Energy Inc. ■ Page 13 ■ 2022 Annual Information Form

The following tables may not total due to rounding.

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Oil and gas reserves - Gross and net interest^(2)^, based on forecast prices and costs^(1)^

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​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Light Crude Oil & Medium Crude Oil (mbbl) ​ Heavy Crude Oil (mbbl) ​ Tight Oil (mbbl) ​ Conventional Natural Gas (mmcf)
Proved Developed Producing ^(3) (5) (6)^ **** Gross ^(2)^ **** Net ^(2)^ **** Gross ^(2)^ **** Net ^(2)^ **** Gross ^(2)^ **** Net ^(2)^ **** Gross ^(2)^ **** Net ^(2)^
Australia ​ 6,403 ​ 6,403 ​ — ​ — ​ — ​ — ​ — ​ —
Canada 43,804 38,853 17 16 2,488 2,154 235,445 216,455
CEE — — — — — — 522 385
France 24,832 21,843 — — — — — —
Germany 4,503 4,378 — — — — 43,627 41,081
Ireland — — — — — — 40,366 40,366
Netherlands — — — — — — 29,382 25,709
United States 7,298 6,068 — — — — 28,743 23,939
Total Proved Developed Producing **** 86,840 **** 77,545 **** 17 **** 16 **** 2,488 **** 2,154 **** 378,085 **** 347,935
North America 51,102 44,921 17 16 2,488 2,154 264,188 240,395
International 35,738 32,624 — — — — 113,897 107,540

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​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Shale Gas (mmcf) ​ Coal Bed Methane (mmcf) ​ Natural Gas Liquids (mbbl) ​ BOE (mboe)
Proved Developed Producing ^(3) (5) (6)^ **** Gross ^(2)^ **** Net ^(2)^ **** Gross ^(2)^ **** Net ^(2)^ **** Gross ^(2)^ **** Net ^(2)^ **** Gross ^(2)^ **** Net ^(2)^
Australia ​ — ​ — ​ — ​ — ​ — ​ — ​ 6,403 ​ 6,403
Canada 59,333 53,077 6,219 5,766 21,322 17,622 117,797 104,528
CEE — — — — — — 87 64
France — — — — — — 24,832 21,843
Germany — — — — — — 11,774 11,225
Ireland — — — — — — 6,728 6,728
Netherlands — — — — 17 14 4,914 4,299
United States — — — — 3,992 3,327 16,081 13,385
Total Proved Developed Producing **** 59,333 **** 53,077 **** 6,219 **** 5,766 **** 25,332 **** 20,964 **** 188,617 **** 168,475
North America 59,333 53,077 6,219 5,766 25,314 20,949 133,879 117,914
International — — — — 17 14 54,738 50,561

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​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Light Crude Oil & Medium Crude Oil (mbbl) ​ Heavy Crude Oil (mbbl) ​ Tight Oil (mbbl) ​ Conventional Natural Gas (mmcf)
Proved Developed Non-Producing ^(3) (5) (7)^ **** Gross ^(2)^ **** Net ^(2)^ **** Gross ^(2)^ **** Net ^(2)^ **** Gross ^(2)^ **** Net ^(2)^ **** Gross ^(2)^ **** Net ^(2)^
Australia ​ — ​ — ​ — ​ — ​ — ​ — ​ — ​ —
Canada 2,678 2,280 — — — — 16,094 14,902
CEE — — — — — — 9,423 5,533
France 348 304 — — — — — —
Germany 1,146 1,120 — — — — 19,354 18,463
Ireland — — — — — — — —
Netherlands — — — — — — 5,557 5,102
United States — — — — — — — —
Total Proved Developed Non-Producing **** 4,172 **** 3,704 **** — **** — **** — **** — **** 50,428 **** 44,001
North America 2,678 2,280 — — — — 16,094 14,902
International 1,494 1,424 — — — — 34,334 29,099

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​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ **** Shale Gas (mmcf) **** Coal Bed Methane (mmcf) **** Natural Gas Liquids (mbbl) **** BOE (mboe)
Proved Developed Non-Producing ^(3) (5) (7)^ ​ Gross ^(2)^ **** Net ^(2)^ ​ Gross ^(2)^ **** Net ^(2)^ ​ Gross ^(2)^ **** Net ^(2)^ ​ Gross ^(2)^ **** Net ^(2)^
Australia ​ — ​ — ​ — ​ — ​ — ​ — ​ — ​ —
Canada 374 307 820 773 1,322 1,145 6,882 6,089
CEE — — — — — — 1,570 922
France — — — — — — 348 304
Germany — — — — — — 4,372 4,197
Ireland — — — — — — — —
Netherlands — — — — 3 3 930 853
United States — — — — — — — —
Total Proved Developed Non-Producing **** 374 **** 307 **** 820 **** 773 **** 1,326 **** 1,148 **** 14,101 **** 12,366
North America 374 307 820 773 1,322 1,145 6,882 6,089
International — — — — 3 3 7,220 6,277

​ Vermilion Energy Inc. ■ Page 14 ■ 2022 Annual Information Form

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Light Crude Oil & Medium Crude Oil (mbbl) ​ Heavy Crude Oil (mbbl) ​ Tight Oil (mbbl) ​ Conventional Natural Gas (mmcf)
Proved Undeveloped ^(3) (8)^ **** Gross ^(2)^ **** Net ^(2)^ **** Gross ^(2)^ **** Net ^(2)^ **** Gross ^(2)^ **** Net ^(2)^ **** Gross ^(2)^ **** Net ^(2)^
Australia ​ — ​ — ​ — ​ — ​ — ​ — ​ — ​ —
Canada 36,437 31,187 84 71 3,623 3,292 93,804 85,267
CEE — — — — — — — —
France 4,348 3,787 — — — — — —
Germany 1,335 1,299 — — — — 4,911 4,603
Ireland — — — — — — — —
Netherlands — — — — — — — —
United States 12,863 10,543 — — — — 18,352 15,044
Total Proved Undeveloped **** 54,984 **** 46,816 **** 84 **** 71 **** 3,623 **** 3,292 **** 117,067 **** 104,914
North America 49,301 41,730 84 71 3,623 3,292 112,156 100,311
International 5,683 5,086 — — — — 4,911 4,603

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ **** Shale Gas (mmcf) **** Coal Bed Methane (mmcf) Natural Gas Liquids (mbbl) BOE (mboe)
Proved Undeveloped ^(3) (8)^ ​ Gross ^(2)^ **** Net ^(2)^ ​ Gross ^(2)^ **** Net ^(2)^ ​ Gross ^(2)^ **** Net ^(2)^ ​ Gross ^(2)^ **** Net ^(2)^
Australia ​ — ​ — ​ — ​ — ​ — ​ — ​ — ​ —
Canada 100,205 88,680 428 342 13,106 11,084 85,656 74,682
CEE — — — — — — — —
France — — — — — — 4,348 3,787
Germany — — — — — — 2,154 2,067
Ireland — — — — — — — —
Netherlands — — — — — — — —
United States — — — — 2,331 1,912 18,253 14,963
Total Proved Undeveloped **** 100,205 **** 88,680 **** 428 **** 342 **** 15,437 **** 12,996 **** 110,411 **** 95,498
North America 100,205 88,680 428 342 15,437 12,996 103,909 89,645
International — — — — — — 6,501 5,853

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Light Crude Oil & Medium Crude Oil (mbbl) ​ Heavy Crude Oil (mbbl) ​ Tight Oil (mbbl) ​ Conventional Natural Gas (mmcf)
Proved ^(3)^ **** Gross ^(2)^ **** Net ^(2)^ **** Gross ^(2)^ **** Net ^(2)^ **** Gross ^(2)^ **** Net ^(2)^ **** Gross ^(2)^ **** Net ^(2)^
Australia ​ 6,403 ​ 6,403 ​ — ​ — ​ — ​ — ​ — ​ —
Canada 82,919 72,319 101 88 6,111 5,446 345,342 316,625
CEE — — — — — — 9,945 5,918
France 29,528 25,934 — — — — — —
Germany 6,984 6,797 — — — — 67,892 64,148
Ireland — — — — — — 40,366 40,366
Netherlands — — — — — — 34,939 30,811
United States 20,162 16,612 — — — — 47,095 38,983
Total Proved **** 145,996 **** 128,065 **** 101 **** 88 **** 6,111 **** 5,446 **** 545,580 **** 496,850
North America 103,081 88,931 101 88 6,111 5,446 392,437 355,608
International 42,915 39,134 — — — — 153,142 141,242

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ **** Shale Gas (mmcf) **** Coal Bed Methane (mmcf) **** Natural Gas Liquids (mbbl) **** BOE (mboe)
Proved ^(3)^ ​ Gross ^(2)^ **** Net ^(2)^ ​ Gross ^(2)^ **** Net ^(2)^ ​ Gross ^(2)^ **** Net ^(2)^ ​ Gross ^(2)^ **** Net ^(2)^
Australia ​ — ​ — ​ — ​ — ​ — ​ — ​ 6,403 ​ 6,403
Canada 159,912 142,064 7,467 6,882 35,750 29,852 210,335 185,300
CEE — — — — — — 1,658 986
France — — — — — — 29,528 25,934
Germany — — — — — — 18,300 17,489
Ireland — — — — — — 6,728 6,728
Netherlands — — — — 21 17 5,844 5,152
United States — — — — 6,324 5,239 34,335 28,348
Total Proved **** 159,912 **** 142,064 **** 7,467 **** 6,882 **** 42,094 **** 35,108 **** 313,129 **** 276,339
North America 159,912 142,064 7,467 6,882 42,074 35,091 244,670 213,647
International — — — — 21 17 68,459 62,691

​

​ Vermilion Energy Inc. ■ Page 15 ■ 2022 Annual Information Form

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Light Crude Oil & Medium Crude Oil (mbbl) ​ Heavy Crude Oil (mbbl) ​ Tight Oil (mbbl) ​ Conventional Natural Gas (mmcf)
Probable ^(4)^ **** Gross ^(2)^ **** Net ^(2)^ **** Gross ^(2)^ **** Net ^(2)^ **** Gross ^(2)^ **** Net ^(2)^ **** Gross ^(2)^ **** Net ^(2)^
Australia ​ 6,129 ​ 6,129 ​ — ​ — ​ — ​ — ​ — ​ —
Canada 39,445 34,427 31 26 6,431 5,820 218,580 197,152
CEE — — — — — — 5,399 3,142
France 9,426 8,238 — — — — — —
Germany 5,431 5,268 — — — — 53,742 49,977
Ireland — — — — — — 24,861 24,861
Netherlands — — — — — — 43,500 39,281
United States 18,511 15,396 — — — — 33,803 28,074
Total Probable **** 78,942 **** 69,458 **** 31 **** 26 **** 6,431 **** 5,820 **** 379,885 **** 342,486
North America 57,956 49,823 31 26 6,431 5,820 252,383 225,225
International 20,986 19,634 — — — — 127,502 117,261

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Shale Gas (mmcf) ​ Coal Bed Methane (mmcf) ​ Natural Gas Liquids (mbbl) ​ BOE (mboe)
Probable ^(4)^ **** Gross ^(2)^ **** Net ^(2)^ **** Gross ^(2)^ **** Net ^(2)^ **** Gross ^(2)^ **** Net ^(2)^ **** Gross ^(2)^ **** Net ^(2)^
Australia ​ — ​ — ​ — ​ — ​ — ​ — ​ 6,129 ​ 6,129
Canada 190,472 164,898 2,637 2,427 23,944 19,422 138,465 120,442
CEE — — — — — — 900 524
France — — — — — — 9,426 8,238
Germany — — — — — — 14,388 13,597
Ireland — — — — — — 4,143 4,143
Netherlands — — — — 50 46 7,300 6,593
United States — — — — 4,765 3,960 28,910 24,035
Total Probable **** 190,472 **** 164,898 **** 2,637 **** 2,427 **** 28,759 **** 23,429 **** 209,661 **** 183,701
North America 190,472 164,898 2,637 2,427 28,709 23,383 167,375 144,477
International — — — — 50 46 42,286 39,224

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Light Crude Oil & Medium Crude Oil (mbbl) ​ Heavy Crude Oil (mbbl) ​ Tight Oil (mbbl) ​ Conventional Natural Gas (mmcf)
Proved Plus Probable ^(3) (4)^ **** Gross ^(2)^ **** Net ^(2)^ **** Gross ^(2)^ **** Net ^(2)^ **** Gross ^(2)^ **** Net ^(2)^ **** Gross ^(2)^ **** Net ^(2)^
Australia ​ 12,531 ​ 12,531 ​ — ​ — ​ — ​ — ​ — ​ —
Canada 122,363 106,747 132 113 12,542 11,266 563,922 513,776
CEE — — — — — — 15,345 9,061
France 38,954 34,172 — — — — — —
Germany 12,416 12,065 — — — — 121,635 114,125
Ireland — — — — — — 65,227 65,227
Netherlands — — — — — — 78,439 70,091
United States 38,673 32,007 — — — — 80,898 67,057
Total Proved Plus Probable **** 224,937 **** 197,522 **** 132 **** 113 **** 12,542 **** 11,266 **** 925,464 **** 839,337
North America 161,036 138,754 132 113 12,542 11,266 644,820 580,833
International 63,901 58,768 — — — — 280,644 258,503

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Shale Gas (mmcf) ​ Coal Bed Methane (mmcf) ​ Natural Gas Liquids (mbbl) ​ BOE (mboe)
Proved Plus Probable ^(3) (4)^ **** Gross ^(2)^ **** Net ^(2)^ **** Gross ^(2)^ **** Net ^(2)^ **** Gross ^(2)^ **** Net ^(2)^ **** Gross ^(2)^ **** Net ^(2)^
Australia — — — — — — 12,531 12,531
Canada 350,384 306,962 10,104 9,309 59,695 49,274 348,800 305,741
CEE — — — — — — 2,557 1,510
France — — — — — — 38,954 34,172
Germany — — — — — — 32,688 31,086
Ireland — — — — — — 10,871 10,871
Netherlands — — — — 70 63 13,143 11,745
United States — — — — 11,089 9,200 63,244 52,383
Total Proved Plus Probable **** 350,384 **** 306,962 **** 10,104 **** 9,309 **** 70,853 **** 58,537 **** 522,790 **** 460,040
North America 350,384 306,962 10,104 9,309 70,783 58,473 412,045 358,124
International — — — — 70 63 110,745 101,915

​

Notes:

(1) The pricing assumptions used in the GLJ Report with respect to net present value of future net revenue (forecast) as well as the inflation rates used for operating and capital costs are set forth in “Forecast Prices used in Estimates”. GLJ is an independent qualified reserves evaluator appointed pursuant to NI 51-101.
(2) "Gross Reserves" are Vermilion's working interest (operating or non-operating) share before deduction of royalty obligations and without including any royalty interests of Vermilion. "Net Reserves" are Vermilion's working interest (operating or non-operating) share after deduction of royalty obligations, plus Vermilion's royalty interests in reserves.
--- ---
(3) "Proved" reserves are those reserves that can be estimated with a high degree of certainty to be recoverable. It is likely that the actual remaining quantities recovered will exceed the estimated proved reserves.
--- ---
(4) "Probable" reserves are those additional reserves that are less certain to be recovered than proved reserves. It is equally likely that the actual remaining quantities recovered will be greater or less than the sum of the estimated proved plus probable reserves.
--- ---

Vermilion Energy Inc. ■ Page 16 ■ 2022 Annual Information Form

(5) "Developed" reserves are those reserves that are expected to be recovered from existing wells and installed facilities or, if facilities have not been installed, that would involve a low expenditure (e.g. when compared to the cost of drilling a well) to put the reserves on production.
(6) "Developed Producing" reserves are those reserves that are expected to be recovered from completion intervals open at the time of the estimate. These reserves may be currently producing or, if shut-in, they must have previously been on production, and the date of resumption of production must be known with reasonable certainty.
--- ---
(7) "Developed Non-Producing" reserves are those reserves that either have not been on production, or have previously been on production, but are shut in, and the date of resumption of production is unknown.
--- ---
(8) "Undeveloped" reserves are those reserves expected to be recovered from known accumulations where a significant expenditure (for example, when compared to the cost of drilling a well) is required to render them capable of production. They must fully meet the requirements of the reserves classification (proved, probable, possible) to which they are assigned.
--- ---

​

​ Vermilion Energy Inc. ■ Page 17 ■ 2022 Annual Information Form

Net present value of future net revenue - Based on forecast prices and costs^(1)^

​

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ Before Deducting Future Income Taxes Discounted At ​ After Deducting Future Income Taxes Discounted At
(M) 0% **** 5% **** 10% **** 15% **** 20% **** 0% **** 5% **** 10% **** 15% **** 20%
Proved Developed Producing (2) (4) (5) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Australia 148,335 197,844 217,664 222,190 218,940 126,827 151,432 159,380 158,957 154,450
Canada 3,415,746 2,545,076 2,073,496 1,772,737 1,561,923 3,380,387 2,538,973 2,072,291 1,772,470 1,561,858
CEE 8,273 7,937 7,629 7,347 7,090 8,273 7,937 7,629 7,347 7,090
France 1,036,925 860,047 717,061 609,878 530,012 878,022 741,894 623,676 532,560 463,731
Germany 919,736 861,436 778,339 706,557 648,513 632,678 599,285 534,810 477,681 431,606
Ireland 960,086 873,508 798,449 734,865 681,270 822,400 739,113 667,118 606,398 555,485
Netherlands 428,518 409,869 388,805 368,535 349,995 284,260 273,942 260,139 246,250 233,363
United States 405,523 320,683 264,337 226,199 199,072 405,523 320,683 264,337 226,199 199,072
Total Proved Developed Producing 7,323,142 **** 6,076,400 **** 5,245,779 **** 4,648,308 **** 4,196,815 **** 6,538,370 **** 5,373,260 **** 4,589,380 **** 4,027,864 **** 3,606,655
North America 3,821,269 2,865,759 2,337,833 1,998,936 1,760,995 3,785,910 2,859,656 2,336,628 1,998,670 1,760,930
International 3,501,873 3,210,640 2,907,946 2,649,372 2,435,820 2,752,461 2,513,604 2,252,752 2,029,195 1,845,725
Proved Developed Non-Producing (2) (4) (6) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Australia — — — — — — — — — —
Canada 224,715 172,621 140,731 119,257 103,845 171,750 149,374 129,722 113,728 100,934
CEE 148,754 132,061 118,412 107,068 97,506 134,226 119,208 106,923 96,711 88,102
France 8,943 8,489 7,011 5,647 4,568 5,869 6,023 4,969 3,910 3,059
Germany 408,281 300,199 227,099 179,880 148,187 267,055 197,328 145,652 111,901 89,378
Ireland — — — — — — — — — —
Netherlands 51,705 58,716 58,346 55,842 52,791 16,733 26,435 28,394 27,924 26,661
United States — — — — — — — — — —
Total Proved Developed Non-Producing 842,398 **** 672,087 **** 551,598 **** 467,694 **** 406,897 **** 595,633 **** 498,367 **** 415,660 **** 354,175 **** 308,134
North America 224,715 172,621 140,731 119,257 103,845 171,750 149,374 129,722 113,728 100,934
International 617,683 499,466 410,867 348,437 303,052 423,883 348,994 285,938 240,447 207,200
Proved Undeveloped (2) (7) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Australia — — — — — — — — — —
Canada 2,304,721 1,531,017 1,072,971 783,544 589,446 1,734,123 1,162,373 821,806 604,896 458,002
CEE — — — — — — — — — —
France 234,607 179,550 138,937 109,305 87,456 170,739 128,765 97,414 74,577 57,863
Germany 139,121 106,201 78,358 58,547 44,604 89,334 68,687 48,838 34,488 24,436
Ireland — — — — — — — — — —
Netherlands — — — — — — — — — —
United States 594,353 375,421 256,139 184,005 136,926 560,269 354,350 242,370 174,587 130,233
Total Proved Undeveloped 3,272,802 **** 2,192,187 **** 1,546,406 **** 1,135,401 **** 858,433 **** 2,554,465 **** 1,714,175 **** 1,210,428 **** 888,547 **** 670,534
North America 2,899,074 1,906,437 1,329,110 967,549 726,372 2,294,392 1,516,723 1,064,176 779,482 588,235
International 373,728 285,750 217,296 167,852 132,061 260,073 197,452 146,252 109,065 82,299
Proved (2) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Australia 148,335 197,844 217,664 222,190 218,940 126,827 151,432 159,380 158,957 154,450
Canada 5,945,182 4,248,714 3,287,198 2,675,537 2,255,214 5,286,260 3,850,719 3,023,819 2,491,094 2,120,795
CEE 157,027 139,998 126,041 114,416 104,597 142,499 127,145 114,552 104,059 95,192
France 1,280,475 1,048,085 863,009 724,830 622,037 1,054,630 876,683 726,058 611,047 524,653
Germany 1,467,138 1,267,836 1,083,796 944,983 841,304 989,067 865,300 729,300 624,071 545,419
Ireland 960,086 873,508 798,449 734,865 681,270 822,400 739,113 667,118 606,398 555,485
Netherlands 480,222 468,585 447,151 424,377 402,785 300,993 300,377 288,533 274,174 260,024
United States 999,876 696,104 520,475 410,205 335,998 965,792 675,033 506,707 400,786 329,304
Total Proved 11,438,342 **** 8,940,674 **** 7,343,782 **** 6,251,403 **** 5,462,145 **** 9,688,468 **** 7,585,802 **** 6,215,468 **** 5,270,586 **** 4,585,323
North America 6,945,058 4,944,818 3,807,674 3,085,742 2,591,212 6,252,051 4,525,753 3,530,526 2,891,880 2,450,099
International 4,493,284 3,995,856 3,536,109 3,165,661 2,870,933 3,436,416 3,060,050 2,684,942 2,378,707 2,135,224

All values are in US Dollars.

​ Vermilion Energy Inc. ■ Page 18 ■ 2022 Annual Information Form

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ Before Deducting Future Income Taxes Discounted At ​ After Deducting Future Income Taxes Discounted At
(M) 0% **** 5% **** 10% **** 15% **** 20% **** 0% **** 5% **** 10% **** 15% **** 20%
Probable (3)
Australia 256,239 237,913 203,133 168,972 139,955 130,270 118,694 98,317 78,789 62,533
Canada 4,450,549 2,596,715 1,728,277 1,250,576 957,469 3,352,441 1,950,632 1,293,930 933,732 713,706
CEE 78,392 66,126 57,136 50,270 44,849 64,699 54,480 47,015 41,331 36,856
France 624,624 425,801 303,264 224,390 171,494 460,190 310,134 217,320 157,683 117,892
Germany 1,309,243 846,078 583,181 431,009 335,897 877,721 568,059 382,718 275,614 209,295
Ireland 471,085 345,570 259,840 201,211 160,320 357,028 267,836 204,758 160,810 129,767
Netherlands 651,452 476,407 361,302 282,908 227,725 361,363 256,225 188,240 142,849 111,545
United States 1,285,011 714,884 460,109 324,836 243,617 1,019,072 563,259 362,096 256,350 193,257
Total Probable 9,126,593 **** 5,709,495 **** 3,956,243 **** 2,934,172 **** 2,281,325 **** 6,622,785 **** 4,089,319 **** 2,794,394 **** 2,047,159 **** 1,574,851
North America 5,735,559 3,311,599 2,188,386 1,575,412 1,201,086 4,371,513 2,513,891 1,656,026 1,190,083 906,963
International 3,391,034 2,397,896 1,767,856 1,358,760 1,080,239 2,251,272 1,575,428 1,138,368 857,076 667,888
Proved Plus Probable (2) (3) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Australia 404,574 435,757 420,796 391,163 358,895 257,097 270,127 257,697 237,746 216,982
Canada 10,395,731 6,845,428 5,015,475 3,926,113 3,212,684 8,638,701 5,801,351 4,317,749 3,424,826 2,834,501
CEE 235,419 206,125 183,177 164,686 149,446 207,199 181,624 161,567 145,390 132,048
France 1,905,099 1,473,887 1,166,273 949,220 793,530 1,514,820 1,186,817 943,379 768,731 642,545
Germany 2,776,381 2,113,914 1,666,977 1,375,992 1,177,201 1,866,788 1,433,359 1,112,019 899,685 754,714
Ireland 1,431,171 1,219,078 1,058,289 936,076 841,590 1,179,428 1,006,948 871,876 767,208 685,253
Netherlands 1,131,674 944,992 808,453 707,284 630,511 662,356 556,602 476,773 417,023 371,570
United States 2,284,886 1,410,988 980,585 735,041 579,614 1,984,864 1,238,292 868,803 657,136 522,561
Total Proved Plus Probable 20,564,935 **** 14,650,170 **** 11,300,025 **** 9,185,575 **** 7,743,470 **** 16,311,252 **** 11,675,121 **** 9,009,862 **** 7,317,745 **** 6,160,174
North America 12,680,617 8,256,417 5,996,060 4,661,154 3,792,298 10,623,565 7,039,643 5,186,552 4,081,962 3,357,062
International 7,884,318 6,393,753 5,303,965 4,524,421 3,951,172 5,687,688 4,635,478 3,823,310 3,235,783 2,803,112

All values are in US Dollars.

​

Notes:

(1) The pricing assumptions used in the GLJ Report with respect to net present value of future net revenue (forecast) as well as the inflation rates used for operating and capital costs are set forth in “Forecast Prices used in Estimates”. GLJ is an independent qualified reserves evaluator appointed pursuant to NI 51-101.
(2) "Proved" reserves are those reserves that can be estimated with a high degree of certainty to be recoverable. It is likely that the actual remaining quantities recovered will exceed the estimated proved reserves.
--- ---
(3) "Probable" reserves are those additional reserves that are less certain to be recovered than proved reserves. It is equally likely that the actual remaining quantities recovered will be greater or less than the sum of the estimated proved plus probable reserves.
--- ---
(4) "Developed" reserves are those reserves that are expected to be recovered from existing wells and installed facilities or, if facilities have not been installed, that would involve a low expenditure (e.g. when compared to the cost of drilling a well) to put the reserves on production.
--- ---
(5) "Developed Producing" reserves are those reserves that are expected to be recovered from completion intervals open at the time of the estimate. These reserves may be currently producing or, if shut-in, they must have previously been on production, and the date of resumption of production must be known with reasonable certainty.
--- ---
(6) "Developed Non-Producing" reserves are those reserves that either have not been on production, or have previously been on production, but are shut in, and the date of resumption of production is unknown.
--- ---
(7) "Undeveloped" reserves are those reserves expected to be recovered from known accumulations where a significant expenditure (for example, when compared to the cost of drilling a well) is required to render them capable of production. They must fully meet the requirements of the reserves classification (proved, probable, possible) to which they are assigned.
--- ---

​ Vermilion Energy Inc. ■ Page 19 ■ 2022 Annual Information Form

Total future net revenue (undiscounted) - Based on forecast prices and costs^(1)^

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Abandonment ​ Future Net ​ ​ ​ Future Net
​ ​ ​ ​ ​ ​ ​ ​ Capital ​ and ​ Revenue ​ ​ ​ Revenue
​ ​ ​ ​ ​ ​ Operating ​ Development ​ Reclamation ​ Before Future ​ Future ​ After Future
($M) ​ Revenue ​ Royalties ​ Costs ^(5)^ ​ Costs ​ Costs ​ Income Taxes ​ Income Taxes ^(4)^ ​ Income Taxes
Proved ^(2)^ **** ​ **** ​ **** ​ **** ​ **** ​ **** ​ **** ​ **** ​
Australia ​ 780,415 ​ — ​ 424,805 ​ — ​ 207,275 ​ 148,335 ​ 21,508 ​ 126,827
Canada ​ 14,002,413 ​ 1,877,696 ​ 4,563,859 ​ 1,258,573 ​ 357,104 ​ 5,945,182 ​ 658,922 ​ 5,286,260
CEE ​ 295,614 ​ 117,391 ​ 16,166 ​ 4,688 ​ 341 ​ 157,027 ​ 14,528 ​ 142,499
France ​ 3,152,685 ​ 381,879 ​ 1,188,780 ​ 81,284 ​ 220,267 ​ 1,280,475 ​ 225,845 ​ 1,054,630
Germany 2,487,146 118,943 624,794 44,058 232,213 1,467,138 478,072 989,067
Ireland 1,183,927 — 139,963 22,627 61,251 960,086 137,687 822,400
Netherlands 1,072,224 159,629 339,481 16,792 76,100 480,222 179,229 300,993
United States 2,868,926 799,863 775,974 262,783 30,430 999,876 34,084 965,792
Total Proved **** 25,843,351 **** 3,455,400 **** 8,073,823 **** 1,690,806 **** 1,184,980 **** 11,438,342 **** 1,749,875 **** 9,688,468
North America 16,871,339 2,677,558 5,339,833 1,521,356 387,534 6,945,058 693,006 6,252,051
International 8,972,012 777,842 2,733,990 169,450 797,446 4,493,284 1,056,868 3,436,416
Proved Plus Probable ^(2) (3)^ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Australia 1,552,738 — 858,692 57,788 231,684 404,574 147,477 257,097
Canada 23,165,965 3,089,145 7,324,103 1,933,710 423,277 10,395,731 1,757,030 8,638,701
CEE 443,092 178,467 24,149 4,688 369 235,419 28,221 207,199
France 4,174,843 510,024 1,354,925 166,112 238,683 1,905,099 390,278 1,514,820
Germany 4,322,377 219,787 932,416 93,857 299,936 2,776,381 909,593 1,866,788
Ireland 1,776,824 — 232,619 44,056 68,978 1,431,171 251,744 1,179,428
Netherlands 2,138,415 267,684 568,545 77,648 92,864 1,131,674 469,318 662,356
United States 5,637,068 1,557,459 1,285,617 466,946 42,160 2,284,886 300,022 1,984,864
Total Proved Plus Probable **** 43,211,323 **** 5,822,566 **** 12,581,066 **** 2,844,805 **** 1,397,950 **** 20,564,935 **** 4,253,683 **** 16,311,252
North America 28,803,034 4,646,605 8,609,720 2,400,656 465,436 12,680,617 2,057,052 10,623,565
International 14,408,289 1,175,962 3,971,346 444,149 932,514 7,884,318 2,196,631 5,687,688

​

Notes:

(1) The pricing assumptions used in the GLJ Report with respect to net present value of future net revenue (forecast) as well as the inflation rates used for operating and capital costs are set forth in “Forecast Prices used in Estimates”. GLJ is an independent qualified reserves evaluator appointed pursuant to NI 51-101.
(2) "Proved" reserves are those reserves that can be estimated with a high degree of certainty to be recoverable. It is likely that the actual remaining quantities recovered will exceed the estimated proved reserves.
--- ---
(3) "Probable" reserves are those additional reserves that are less certain to be recovered than proved reserves. It is equally likely that the actual remaining quantities recovered will be greater or less than the sum of the estimated proved plus probable reserves.
--- ---
(4) "Future Income Taxes" are calculated using future net revenue before income taxes as shown, after incorporating Vermilion's existing tax pools, corporate charge-outs, and related expenditures. This calculation applies the year-end statutory rate, taking into account future tax rates already legislated.
--- ---
(5) Capital Development Costs include the costs for the drilling, completion, and tie-in of wells, the construction of production and processing facilities, major facilities projects and well workovers. For the purposes of determining Future Net Revenue, costs related to the replacement of certain downhole and facilities equipment as well as facility turnarounds are included in Operating Costs.
--- ---

​ Vermilion Energy Inc. ■ Page 20 ■ 2022 Annual Information Form

Future net revenue by product type - Based on forecast prices and costs^(1)^

​

​ ​ ​ ​ ​
​ **** Future Net Revenue **** ​
​ ​ Before Income Taxes^(2)^ ​ ​
​ ​ (Discounted at 10% Per Year) ​ Unit Value ($/boe)
​ ​ ($M) ​ ​
Proved Developed Producing
Light Crude Oil & Medium Crude Oil ^(3)^ 2,535,555 ​ 25.34
Heavy Crude Oil ^(3)^ 1,071 ​ 36.12
Tight Oil 195,425 ​ 17.48
Conventional Natural Gas ^(4)^ 2,479,863 ​ 34.44
Shale Gas 22,164 ​ 11.90
Coal Bed Methane 11,700 ​ 10.24
Total Proved Developed Producing **** 5,245,779 ​ 28.16
Proved Developed Non-Producing ​ ​ ​
Light Crude Oil & Medium Crude Oil ^(3)^ 138,222 ​ 28.05
Heavy Crude Oil ^(3)^ 12 ​ 19.50
Tight Oil ​ — ​ —
Conventional Natural Gas ^(4)^ 411,429 ​ 45.86
Shale Gas 551 ​ 7.98
Coal Bed Methane 1,384 ​ 9.23
Total Proved Developed Non-Producing **** 551,598 ​ 39.20
Proved Undeveloped ​ ​ ​
Light Crude Oil & Medium Crude Oil ^(3)^ 1,233,640 ​ 18.73
Heavy Crude Oil ^(3)^ 2,378 ​ 16.48
Tight Oil 69,084 ​ 7.88
Conventional Natural Gas ^(4)^ 201,088 ​ 11.13
Shale Gas 39,629 ​ 2.79
Coal Bed Methane 586 ​ 7.50
Total Proved Undeveloped **** 1,546,406 ​ 14.43
Proved ​ ​ ​
Light Crude Oil & Medium Crude Oil ^(3)^ 3,907,417 ​ 22.87
Heavy Crude Oil ^(3)^ 3,461 ​ 19.83
Tight Oil ​ 264,509 ​ 13.26
Conventional Natural Gas ^(4)^ ​ 3,092,380 ​ 31.22
Shale Gas 62,345 ​ 3.87
Coal Bed Methane ​ 13,670 ​ 9.98
Total Proved **** 7,343,782 ​ 23.88
Probable ​ ​ ​
Light Crude Oil & Medium Crude Oil ^(3)^ 2,126,992 ​ 22.24
Heavy Crude Oil ^(3)^ 1,252 ​ 23.74
Tight Oil 104,941 ​ 7.97
Conventional Natural Gas ^(4)^ 1,525,085 ​ 23.19
Shale Gas 194,654 ​ 6.53
Coal Bed Methane 3,319 ​ 6.86
Total Probable **** 3,956,243 ​ 19.31
Proved Plus Probable ​ ​ ​
Light Crude Oil & Medium Crude Oil ^(3)^ 6,034,409 ​ 22.64
Heavy Crude Oil ^(3)^ 4,713 ​ 20.74
Tight Oil ​ 369,450 ​ 11.16
Conventional Natural Gas ^(4)^ 4,617,465 ​ 28.02
Shale Gas 256,999 ​ 5.59
Coal Bed Methane 16,989 ​ 9.16
Total Proved Plus Probable **** 11,300,025 ​ 22.05

​

Notes:

(1) The pricing assumptions used in the GLJ Report with respect to net present value of future net revenue (forecast) as well as the inflation rates used for operating and capital costs are set forth in “Forecast Prices used in Estimates”. GLJ is an independent qualified reserves evaluator appointed pursuant to NI 51-101.
(2) Other Company revenue and costs not related to a specific product type have been allocated proportionately to the specified product types. Unit values are based on Company net reserves. Net present value of reserves categories are an approximation based on major products.
--- ---
(3) Including solution gas and other by-products.
--- ---
(4) Including by-products but excluding solution gas.
--- ---

​ Vermilion Energy Inc. ■ Page 21 ■ 2022 Annual Information Form

Forecast prices used in estimates^(1)(2)^

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Light Crude Oil & Medium ​ Conventional Natural Gas ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Crude Oil Crude Oil Canada Europe Natural Gas Liquids Inflation Rate ​ Exchange Rate
​ ​ WTI ​ Edmonton Cromer Brent Blend ​ UK National ​ ​ ​ ​ ​ ​ ​ ​
​ **** Cushing **** Par Price Light FOB AECO Balancing Edmonton Edmonton Edmonton ​ ​ ​ ​ ​
​ ​ Oklahoma ​ 40˚ API 35˚ API North Sea Gas Price Point Ethane Propane Butane Edmonton C5+ ​ ​ ​ ​
Year ​ ($US/bbl) ​ (Cdn/bbl) (Cdn/bbl) (US/bbl) (Cdn/mmbtu) (US/mmbtu) (Cdn/bbl) (Cdn/bbl) (Cdn/bbl) (Cdn/bbl) Percent Per Year **** /CAD CAD/EUR
2022 94.23 120.03 117.97 101.19 5.56 24.50 19.26 33.78 55.76 105.76 6.90 % 0.77 1.37
Forecast ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
2023 80.33 103.77 104.27 84.67 4.23 33.83 13.75 39.80 53.88 106.22 - % 0.75 1.45
2024 76.71 97.74 98.21 82.69 4.40 27.38 14.33 39.13 52.67 101.35 2.30 % 0.77 1.43
2025 73.72 95.27 95.73 81.03 4.21 20.00 13.77 39.74 51.42 98.94 2.00 % 0.77 1.44
2026 72.89 95.58 96.03 81.39 4.27 17.30 13.98 39.86 51.61 100.19 2.00 % 0.77 1.44
2027 72.89 97.07 97.53 82.65 4.34 16.47 14.20 40.47 52.39 101.74 2.00 % 0.78 1.44
2028 72.90 99.01 99.47 84.29 4.43 16.80 14.49 41.28 53.44 103.78 2.00 % 0.78 1.44
2029 72.90 100.99 101.46 85.98 4.51 17.14 14.79 42.11 54.51 105.85 2.00 % 0.78 1.44
2030 72.89 103.01 103.49 87.70 4.60 17.48 15.09 42.95 55.60 107.97 2.00 % 0.78 1.44
2031 72.89 105.07 105.57 89.46 4.69 17.83 15.39 43.81 56.71 110.13 2.00 % 0.78 1.44
2032 72.90 106.69 107.19 91.25 4.79 18.19 15.71 44.47 57.56 112.33 2.00 % 0.78 1.44
Thereafter +2.0%/yr +2.0%/yr +2.0%/yr +2.0%/yr +2.0%/yr +2.0%/yr +2.0%/yr +2.0%/yr +2.0%/yr +2.0%/yr +2.0%/yr 0.78 1.44

All values are in US Dollars.

​

Notes:

(1) The pricing assumptions used in the GLJ Report with respect to net present value of future net revenue (forecast) as well as the inflation rates used for operating and capital costs are set forth above. The pricing assumptions above are the January 2023, 3 Consultants' Average pricing which were provided by GLJ, an independent qualified reserves evaluator appointed pursuant to NI 51-101. The consultants are GLJ, Sproule and McDaniel and Associates, all independent qualified reverse evaluators.
(2) For light crude oil and medium crude oil, the pricing assumptions used are WTI, Edmonton Par Price, Cromer Medium, and Brent Blend. For conventional natural gas in Canada, the pricing assumptions used are AECO and for conventional natural gas in Europe, the pricing assumptions used are National Balancing Point.
--- ---

​

For 2022, average realized prices before hedging were:

​

​ ​ ​ ​ ​ ​
​ **** Crude **** NGLs Natural gas
Country ​ oil ($/bbl) ​ (/bbl) ($/mcf)
Australia ​ 148.15 ​ — —
Canada ​ 116.04 ​ 74.26 6.07
CEE — ​ — 52.02
France 132.90 ​ — —
Germany 128.00 ​ — 43.84
Ireland — ​ — 32.34
Netherlands — ​ 87.13 47.04
United States 121.59 ​ 51.00 6.36

All values are in US Dollars.

​

​ Vermilion Energy Inc. ■ Page 22 ■ 2022 Annual Information Form

Reconciliations of changes in reserves

​

​

The following tables set forth a reconciliation of the changes by product type (light crude oil and medium crude oil, heavy crude oil, tight oil, conventional natural gas, coal bed methane, shale gas and NGLs) in Vermilion's gross reserves as at December 31, 2022 compared to such reserves as at December 31, 2021 based on the forecast price and cost assumptions set forth in note 3.

​

Reconciliation of Company Gross Reserves by Principal Product Type - Based on Forecast Prices and Costs ^(3)^

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Australia ​ Total Oil^(4)^ ​ Light & Medium Crude Oil ​ Heavy Crude Oil ​ Tight Oil
Proved Probable P+P ^(1) (2)^ **** Proved **** Probable **** P+P **** Proved **** Probable **** P+P **** Proved **** Probable **** P+P **** Proved **** Probable **** P+P
Factors ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl)
At December 31, 2021 7,855 4,912 12,768 7,855 4,912 12,768 — — — — — —
Discoveries — — — — — — — — — — — —
Extensions & Improved Recovery^(5)^ — 1,690 1,690 — 1,690 1,690 — — — — — —
Technical Revisions^(6)^ 6 (474) (468) 6 (474) (468) — — — — — —
Acquisitions^(7)^ — — — — — — — — — — — —
Dispositions — — — — — — — — — — — —
Economic Factors^(8)^ — — — — — — — — — — — —
Production (1,458) — (1,458) (1,458) — (1,458) — — — — — —
At December 31, 2022 **** 6,403 **** 6,129 **** 12,531 **** 6,403 **** 6,129 **** 12,531 **** — **** — **** — **** — **** — **** —

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Australia **** Total Gas^(4)^ **** Conventional Natural Gas **** Coal Bed Methane Shale Gas
Proved Probable P+P ^(1) (2)^ ​ Proved **** Probable **** P+P **** Proved **** Probable **** P+P **** Proved **** Probable **** P+P **** Proved **** Probable **** P+P
Factors ​ (mmcf) **** ​ (mmcf) **** ​ (mmcf) ​ (mmcf) **** ​ (mmcf) **** ​ (mmcf) ​ (mmcf) **** ​ (mmcf) **** ​ (mmcf) ​ (mmcf) **** ​ (mmcf) **** ​ (mmcf)
At December 31, 2021 — — — — — — — — — — — —
Discoveries — — — — — — — — — — — —
Extensions & Improved Recovery^(5)^ — — — — — — — — — — — —
Technical Revisions^(6)^ — — — — — — — — — — — —
Acquisitions^(7)^ — — — — — — — — — — — —
Dispositions — — — — — — — — — — — —
Economic Factors^(8)^ — — — — — — — — — — — —
Production — — — — — — — — — — — —
At December 31, 2022 **** — **** — **** — **** — **** — **** — **** — **** — **** — **** — **** — **** —

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Australia **** Natural Gas Liquids BOE
Proved Probable P+P ^(1) (2)^ ​ Proved **** Probable **** P+P **** Proved **** Probable **** P+P
Factors ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mboe) ​ (mboe) ​ (mboe)
At December 31, 2021 — — — 7,855 4,912 12,768
Discoveries — — — — — —
Extensions & Improved Recovery^(5)^ — — — — 1,690 1,690
Technical Revisions^(6)^ — — — 6 (474) (468)
Acquisitions^(7)^ — — — — — —
Dispositions — — — — — —
Economic Factors^(8)^ — — — — — —
Production — — — (1,458) — (1,458)
At December 31, 2022 **** — **** — **** — **** 6,403 **** 6,129 **** 12,531

​

​ Vermilion Energy Inc. ■ Page 23 ■ 2022 Annual Information Form

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Canada **** Total Oil^(4)^ **** Light & Medium Crude Oil Heavy Crude Oil Tight Oil
Proved Probable P+P ^(1) (2)^ ​ Proved **** Probable **** P+P **** Proved **** Probable **** P+P **** Proved **** Probable **** P+P **** Proved **** Probable **** P+P
Factors ​ (mbbl) **** ​ (mbbl) **** ​ (mbbl) ​ (mbbl) **** ​ (mbbl) **** ​ (mbbl) ​ (mbbl) **** ​ (mbbl) **** ​ (mbbl) ​ (mbbl) **** ​ (mbbl) **** ​ (mbbl)
At December 31, 2021 85,575 45,405 130,980 85,471 45,374 130,845 103 31 135 — — —
Discoveries — — — — — — — — — — — —
Extensions & Improved Recovery^(5)^ 4,694 2,952 7,646 1,526 808 2,334 — — — 3,168 2,144 5,312
Technical Revisions^(6)^ 738 (6,639) (5,901) 600 (6,500) (5,900) 3 (1) 3 134 (138) (4)
Acquisitions^(7)^ 3,233 4,467 7,700 190 83 273 — — — 3,043 4,384 7,427
Dispositions (26) (11) (36) (26) (11) (36) — — — — — —
Economic Factors^(8)^ 1,061 (268) 792 1,060 (309) 750 — — — 1 41 42
Production (6,143) — (6,142) (5,902) — (5,902) (5) — (5) (235) — (235)
At December 31, 2022 **** 89,131 **** 45,906 **** 135,038 **** 82,919 **** 39,445 **** 122,364 **** 101 **** 31 **** 132 **** 6,111 **** 6,431 **** 12,542

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Canada **** Total Gas^(4)^ **** Conventional Natural Gas Coal Bed Methane Shale Gas
Proved Probable P+P ^(1) (2)^ ​ Proved **** Probable **** P+P **** Proved **** Probable **** P+P **** Proved **** Probable **** P+P **** Proved **** Probable **** P+P
Factors ​ (mmcf) **** ​ (mmcf) **** ​ (mmcf) ​ (mmcf) **** ​ (mmcf) **** ​ (mmcf) ​ (mmcf) **** ​ (mmcf) **** ​ (mmcf) ​ (mmcf) **** ​ (mmcf) **** ​ (mmcf)
At December 31, 2021 375,230 231,405 606,635 368,752 229,394 598,146 6,121 1,907 8,029 356 105 461
Discoveries — — — — — — — — — — — —
Extensions & Improved Recovery^(5)^ 94,637 71,978 166,615 18,739 13,182 31,921 — — — 75,898 58,796 134,694
Technical Revisions^(6)^ 4,369 (28,649) (24,280) 28 (24,577) (24,549) 645 (3) 642 3,697 (4,070) (373)
Acquisitions^(7)^ 84,303 134,261 218,563 6 3 8 — — — 84,297 134,258 218,555
Dispositions (155) (254) (409) (155) (254) (409) — — — — — —
Economic Factors^(8)^ 6,936 2,948 9,883 5,263 832 6,096 1,618 733 2,351 54 1,383 1,437
Production (52,598) — (52,598) (47,291) — (47,291) (917) — (917) (4,390) — (4,390)
At December 31, 2022 **** 512,721 **** 411,688 **** 924,409 **** 345,342 **** 218,580 **** 563,922 **** 7,467 **** 2,637 **** 10,104 **** 159,912 **** 190,472 **** 350,384

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Canada **** Natural Gas Liquids BOE
Proved Probable P+P ^(1) (2)^ ​ Proved **** Probable **** P+P ​ Proved **** Probable **** P+P
Factors ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mboe) ​ (mboe) ​ (mboe)
At December 31, 2021 34,231 21,148 55,379 182,344 105,121 287,465
Discoveries — — — — — —
Extensions & Improved Recovery^(5)^ 2,922 1,893 4,815 23,389 16,841 40,229
Technical Revisions^(6)^ 859 (1,497) (638) 2,325 (12,911) (10,586)
Acquisitions^(7)^ 1,612 2,375 3,986 18,895 29,218 48,113
Dispositions (10) (29) (38) (61) (82) (143)
Economic Factors^(8)^ 340 55 395 2,556 278 2,834
Production (4,203) — (4,203) (19,113) — (19,112)
At December 31, 2022 **** 35,750 **** 23,945 **** 59,695 **** 210,334 **** 138,466 **** 348,800

​

​ Vermilion Energy Inc. ■ Page 24 ■ 2022 Annual Information Form

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
CEE **** Total Oil^(4)^ **** Light & Medium Crude Oil Heavy Crude Oil Tight Oil
Proved Probable P+P ^(1) (2)^ ​ Proved **** Probable **** P+P ​ Proved **** Probable **** P+P ​ Proved **** Probable **** P+P ​ Proved **** Probable **** P+P
Factors ​ (mbbl) **** ​ (mbbl) **** ​ (mbbl) ​ (mbbl) **** ​ (mbbl) **** ​ (mbbl) ​ (mbbl) **** ​ (mbbl) **** ​ (mbbl) **** ​ (mbbl) **** ​ (mbbl) **** ​ (mbbl)
At December 31, 2021 — — — — — — — — — — — —
Discoveries — — — — — — — — — — — —
Extensions & Improved Recovery^(5)^ — — — — — — — — — — — —
Technical Revisions^(6)^ — — — — — — — — — — — —
Acquisitions^(7)^ — — — — — — — — — — — —
Dispositions — — — — — — — — — — — —
Economic Factors^(8)^ — — — — — — — — — — — —
Production — — — — — — — — — — — —
At December 31, 2022 **** — **** — **** — **** — **** — **** — **** — **** — **** — **** — **** — **** —

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
CEE **** Total Gas^(4)^ **** Conventional Natural Gas Coal Bed Methane Shale Gas
Proved Probable P+P ^(1) (2)^ ​ Proved **** Probable **** P+P **** Proved **** Probable **** P+P ​ Proved **** Probable **** P+P **** Proved **** Probable **** P+P
Factors ​ (mmcf) ​ (mmcf) ​ (mmcf) ​ (mmcf) ​ (mmcf) ​ (mmcf) ​ (mmcf) ​ (mmcf) ​ (mmcf) ​ (mmcf) ​ (mmcf) ​ (mmcf)
At December 31, 2021 10,573 5,676 16,250 10,573 5,676 16,250 — — — — — —
Discoveries — — — — — — — — — — — —
Extensions & Improved Recovery^(5)^ — — — — — — — — — — — —
Technical Revisions^(6)^ (410) (354) (764) (410) (354) (764) — — — — — —
Acquisitions^(7)^ — — — — — — — — — — — —
Dispositions — — — — — — — — — — — —
Economic Factors^(8)^ (10) 77 67 (10) 77 67 — — — — — —
Production (208) — (208) (208) — (208) — — — — — —
At December 31, 2022 **** 9,945 **** 5,399 **** 15,345 **** 9,945 **** 5,399 **** 15,345 **** — **** — **** — **** — **** — **** —

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
CEE **** Natural Gas Liquids BOE
Proved Probable P+P ^(1) (2)^ ​ Proved **** Probable **** P+P **** Proved **** Probable **** P+P
Factors ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mboe) ​ (mboe) ​ (mboe)
At December 31, 2021 — — — 1,762 946 2,708
Discoveries — — — — — —
Extensions & Improved Recovery^(5)^ — — — — — —
Technical Revisions^(6)^ — — — (68) (59) (127)
Acquisitions^(7)^ — — — — — —
Dispositions — — — — — —
Economic Factors^(8)^ — — — (2) 13 11
Production — — — (35) — (35)
At December 31, 2022 **** — **** — **** — **** 1,658 **** 900 **** 2,557

​

​ Vermilion Energy Inc. ■ Page 25 ■ 2022 Annual Information Form

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
France ​ Total Oil ^(4)^ **** Light & Medium Crude Oil **** Heavy Crude Oil **** Tight Oil
Proved Probable P+P ^(1) (2)^ **** Proved **** Probable **** P+P **** Proved **** Probable **** P+P **** Proved **** Probable **** P+P **** Proved **** Probable P+P
Factors ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl)
At December 31, 2021 33,627 12,218 45,845 33,627 12,218 45,845 — — — — — —
Discoveries — — — — — — — — — — — —
Extensions & Improved Recovery^(5)^ 76 29 105 76 29 105 — — — — — —
Technical Revisions^(6)^ (2,386) (2,878) (5,264) (2,386) (2,878) (5,264) — — — — — —
Acquisitions^(7)^ — — — — — — — — — — — —
Dispositions — — — — — — — — — — — —
Economic Factors^(8)^ 999 57 1,056 999 57 1,056 — — — — — —
Production (2,788) — (2,788) (2,788) — (2,788) — — — — — —
At December 31, 2022 **** 29,528 **** 9,426 **** 38,954 **** 29,528 **** 9,426 **** 38,954 **** — **** — **** — **** — **** — **** —

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
France **** Total Gas^(4)^ **** Conventional Natural Gas **** Coal Bed Methane **** Shale Gas
Proved Probable P+P ^(1) (2)^ ​ Proved **** Probable **** P+P **** Proved **** Probable **** P+P **** Proved **** Probable **** P+P **** Proved **** Probable **** P+P
Factors ​ (mmcf) **** ​ (mmcf) **** ​ (mmcf) **** ​ (mmcf) **** ​ (mmcf) **** ​ (mmcf) **** ​ (mmcf) **** ​ (mmcf) **** ​ (mmcf) **** ​ (mmcf) **** ​ (mmcf) **** ​ (mmcf)
At December 31, 2021 — — — — — — — — — — — —
Discoveries — — — — — — — — — — — —
Extensions & Improved Recovery^(5)^ — — — — — — — — — — — —
Technical Revisions^(6)^ — — — — — — — — — — — —
Acquisitions^(7)^ — — — — — — — — — — — —
Dispositions — — — — — — — — — — — —
Economic Factors^(8)^ — — — — — — — — — — — —
Production — — — — — — — — — — — —
At December 31, 2022 **** — **** — **** — **** — **** — **** — **** — **** — **** — **** — **** — **** —

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
France **** Natural Gas Liquids **** BOE
Proved Probable P+P ^(1) (2)^ ​ Proved **** Probable **** P+P **** Proved **** Probable **** P+P
Factors ​ (mbbl) **** ​ (mbbl) **** ​ (mbbl) ​ (mboe) **** ​ (mboe) **** ​ (mboe)
At December 31, 2021 — — — 33,627 12,218 45,845
Discoveries — — — — — —
Extensions & Improved Recovery^(5)^ — — — 76 29 105
Technical Revisions^(6)^ — — — (2,386) (2,878) (5,264)
Acquisitions^(7)^ — — — — — —
Dispositions — — — — — —
Economic Factors^(8)^ — — — 999 57 1,056
Production — — — (2,788) — (2,788)
At December 31, 2022 **** — **** — **** — **** 29,528 **** 9,426 **** 38,954

​

​ Vermilion Energy Inc. ■ Page 26 ■ 2022 Annual Information Form

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Germany **** Total Oil^(4)^ **** Light & Medium Crude Oil **** Heavy Crude Oil **** Tight Oil
Proved Probable P+P ^(1) (2)^ ​ Proved **** Probable **** P+P ​ Proved **** Probable **** P+P ​ Proved **** Probable **** P+P ​ Proved **** Probable **** P+P
Factors ​ (mbbl) **** ​ (mbbl) **** ​ (mbbl) ​ (mbbl) **** ​ (mbbl) **** ​ (mbbl) ​ (mbbl) **** ​ (mbbl) **** ​ (mbbl) ​ (mbbl) **** ​ (mbbl) **** ​ (mbbl)
At December 31, 2021 6,798 4,815 11,613 6,798 4,815 11,613 — — — — — —
Discoveries — — — — — — — — — — — —
Extensions & Improved Recovery^(5)^ 525 725 1,250 525 725 1,250 — — — — — —
Technical Revisions^(6)^ (202) (72) (274) (202) (72) (274) — — — — — —
Acquisitions^(7)^ — — — — — — — — — — — —
Dispositions — — — — — — — — — — — —
Economic Factors^(8)^ 387 (36) 351 387 (36) 351 — — — — — —
Production (524) — (524) (524) — (524) — — — — — —
At December 31, 2022 **** 6,984 **** 5,431 **** 12,416 **** 6,984 **** 5,431 **** 12,416 **** — **** — **** — **** — **** — **** —

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Germany **** Total Gas^(4)^ **** Conventional Natural Gas **** Coal Bed Methane **** Shale Gas
Proved Probable P+P ^(1) (2)^ ​ Proved **** Probable **** P+P ​ Proved **** Probable **** P+P ​ Proved **** Probable **** P+P ​ Proved **** Probable **** P+P
Factors ​ (mmcf) **** ​ (mmcf) **** ​ (mmcf) ​ (mmcf) **** ​ (mmcf) **** ​ (mmcf) ​ (mmcf) **** ​ (mmcf) **** ​ (mmcf) ​ (mmcf) **** ​ (mmcf) **** ​ (mmcf)
At December 31, 2021 72,678 55,943 128,621 72,678 55,943 128,621 — — — — — —
Discoveries — — — — — — — — — — — —
Extensions & Improved Recovery^(5)^ 92 71 163 92 71 163 — — — — — —
Technical Revisions^(6)^ 2,397 (1,494) 904 2,397 (1,494) 904 — — — — — —
Acquisitions^(7)^ — — — — — — — — — — — —
Dispositions — — — — — — — — — — — —
Economic Factors^(8)^ 2,278 (777) 1,501 2,278 (777) 1,501 — — — — — —
Production (9,554) — (9,554) (9,554) — (9,554) — — — — — —
At December 31, 2022 **** 67,892 **** 53,742 **** 121,635 **** 67,892 **** 53,742 **** 121,635 **** — **** — **** — **** — **** — **** —

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Germany **** Natural Gas Liquids BOE
Proved Probable P+P ^(1) (2)^ ​ Proved **** Probable **** P+P **** Proved **** Probable **** P+P
Factors ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mboe) ​ (mboe) ​ (mboe)
At December 31, 2021 — — — 18,911 14,139 33,050
Discoveries — — — — — —
Extensions & Improved Recovery^(5)^ — — — 540 737 1,277
Technical Revisions^(6)^ — — — 197 (321) (124)
Acquisitions^(7)^ — — — — — —
Dispositions — — — — — —
Economic Factors^(8)^ — — — 767 (166) 601
Production — — — (2,116) — (2,116)
At December 31, 2022 **** — **** — **** — **** 18,300 **** 14,388 **** 32,688

​

​ Vermilion Energy Inc. ■ Page 27 ■ 2022 Annual Information Form

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Ireland **** Total Oil ^(4)^ **** Light & Medium Crude Oil Heavy Crude Oil Tight Oil
Proved Probable P+P ^(1) (2)^ ​ Proved **** Probable **** P+P ​ Proved **** Probable **** P+P ​ Proved **** Probable **** P+P **** Proved **** Probable ​ P+P
Factors ​ (mbbl) **** ​ (mbbl) **** ​ (mbbl) ​ (mbbl) **** ​ (mbbl) ​ (mbbl) ​ (mbbl) **** ​ (mbbl) **** ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl)
At December 31, 2021 — — — — — — — — — — — —
Discoveries — — — — — — — — — — — —
Extensions & Improved Recovery^(5)^ — — — — — — — — — — — —
Technical Revisions^(6)^ — — — — — — — — — — — —
Acquisitions^(7)^ — — — — — — — — — — — —
Dispositions — — — — — — — — — — — —
Economic Factors^(8)^ — — — — — — — — — — — —
Production — — — — — — — — — — — —
At December 31, 2022 **** — **** — **** — **** — **** — **** — **** — **** — **** — **** — **** — **** —

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Ireland **** Total Gas ^(4)^ **** Conventional Natural Gas Coal Bed Methane Shale Gas
Proved Probable P+P ^(1) (2)^ ​ Proved **** Probable **** P+P ​ Proved **** Probable **** P+P ​ Proved **** Probable **** P+P **** Proved **** Probable ​ P+P
Factors ​ (mmcf) ​ (mmcf) ​ (mmcf) ​ (mmcf) ​ (mmcf) ​ (mmcf) ​ (mmcf) ​ (mmcf) ​ (mmcf) ​ (mmcf) ​ (mmcf) ​ (mmcf)
At December 31, 2021 50,427 25,431 75,858 50,427 25,431 75,858 — — — — — —
Discoveries — — — — — — — — — — — —
Extensions & Improved Recovery^(5)^ — — — — — — — — — — — —
Technical Revisions^(6)^ (33) (570) (603) (33) (570) (603) — — — — — —
Acquisitions^(7)^ — — — — — — — — — — — —
Dispositions — — — — — — — — — — — —
Economic Factors^(8)^ — — — — — — — — — — — —
Production (10,029) — (10,029) (10,029) — (10,029) — — — — — —
At December 31, 2022 **** 40,366 **** 24,861 **** 65,227 **** 40,366 **** 24,861 **** 65,227 **** — **** — **** — **** — **** — **** —

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Ireland **** Natural Gas Liquids BOE
Proved Probable P+P ^(1) (2)^ ​ Proved **** Probable **** P+P ​ Proved **** Probable **** P+P
Factors ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mboe) ​ (mboe) ​ (mboe)
At December 31, 2021 — — — 8,405 4,238 12,643
Discoveries — — — — — —
Extensions & Improved Recovery^(5)^ — — — — — —
Technical Revisions^(6)^ — — — (5) (95) (100)
Acquisitions^(7)^ — — — — — —
Dispositions — — — — — —
Economic Factors^(8)^ — — — — — —
Production — — — (1,671) — (1,671)
At December 31, 2022 **** — **** — **** — **** 6,728 **** 4,143 **** 10,871

​

​ Vermilion Energy Inc. ■ Page 28 ■ 2022 Annual Information Form

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Netherlands **** Total Oil ^(4)^ **** Light & Medium Crude Oil Heavy Crude Oil Tight Oil
Proved Probable P+P ^(1) (2)^ ​ Proved **** Probable **** P+P ​ Proved **** Probable **** P+P ​ Proved **** Probable **** P+P **** Proved **** Probable **** P+P
Factors ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl) ​ (mbbl)
At December 31, 2021 — — — — — — — — — — — —
Discoveries — — — — — — — — — — — —
Extensions & Improved Recovery^(5)^ — — — — — — — — — — — —
Technical Revisions^(6)^ — — — — — — — — — — — —
Acquisitions^(7)^ — — — — — — — — — — — —
Dispositions — — — — — — — — — — — —
Economic Factors^(8)^ — — — — — — — — — — — —
Production — — — — — — — — — — — —
At December 31, 2022 **** — **** — **** — **** — **** — **** — **** — **** — **** — **** — **** — **** —

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Netherlands ​ Total Gas^(4)^ ​ Conventional Natural Gas Coal Bed Methane ​ Shale Gas
Proved Probable P+P ^(1) (2)^ ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P
Factors **** (mmcf) **** (mmcf) **** (mmcf) **** (mmcf) **** (mmcf) **** (mmcf) **** (mmcf) **** (mmcf) **** (mmcf) **** (mmcf) **** (mmcf) **** (mmcf)
At December 31, 2021 47,522 48,560 96,082 47,522 48,560 96,082 — — — — — —
Discoveries — — - — — - — — — — — —
Extensions & Improved Recovery^(5)^ 597 298 895 597 298 895 — — — — — —
Technical Revisions^(6)^ (4,738) (6,393) (11,130) (4,738) (6,393) (11,130) — — — — — —
Acquisitions^(7)^ — — - — — - — — — — — —
Dispositions (104) (55) (158) (104) (55) (158) — — — — — —
Economic Factors^(8)^ 3,582 1,089 4,671 3,582 1,089 4,671 — — — — — —
Production (11,921) — (11,921) (11,921) — (11,921) — — — — — —
At December 31, 2022 **** 34,939 **** 43,500 **** 78,439 **** 34,939 **** 43,500 **** 78,439 **** — **** — **** — **** — **** — **** —

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Netherlands ​ Natural Gas Liquids ​ BOE
Proved Probable P+P ^(1) (2)^ ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P
Factors **** (mbbl) **** (mbbl) **** (mbbl) **** (mboe) **** (mboe) **** (mboe)
At December 31, 2021 93 107 200 8,013 8,200 16,213
Discoveries - - — - - —
Extensions & Improved Recovery^(5)^ 1 - 1 100 50 150
Technical Revisions^(6)^ (55) (61) (115) (844) (1,126) (1,970)
Acquisitions^(7)^ - - — - - —
Dispositions - - — (17) (9) (26)
Economic Factors^(8)^ 6 3 9 603 185 788
Production (24) - (24) (2,011) - (2,011)
At December 31, 2022 **** 21 **** 50 **** 70 **** 5,844 **** 7,300 **** 13,143

​

​ Vermilion Energy Inc. ■ Page 29 ■ 2022 Annual Information Form

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
United States ​ Total Oil^(4)^ ​ Light & Medium Crude Oil ​ Heavy Crude Oil ​ Tight Oil
Proved Probable P+P ^(1) (2)^ ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P
Factors **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl)
At December 31, 2021 22,735 19,296 42,031 22,735 19,296 42,031 — — — — — —
Discoveries — — — — — — — — — — — —
Extensions & Improved Recovery^(5)^ 2,256 2,414 4,671 2,256 2,414 4,671 — — — — — —
Technical Revisions^(6)^ (4,214) (3,597) (7,811) (4,214) (3,597) (7,811) — — — — — —
Acquisitions^(7)^ — — — — — — — — — — — —
Dispositions — — — — — — — — — — — —
Economic Factors^(8)^ 446 398 844 446 398 844 — — — — — —
Production (1,061) — (1,061) (1,061) — (1,061) — — — — — —
At December 31, 2022 **** 20,162 **** 18,511 **** 38,673 **** 20,162 **** 18,511 **** 38,673 **** — **** — **** — **** — **** — **** —

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
United States ​ Total Gas^(4)^ ​ Conventional Natural Gas ​ Coal Bed Methane^(5)^ ​ Shale Gas
Proved Probable P+P ^(1) (2)^ ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P
Factors **** (mmcf) **** (mmcf) **** (mmcf) **** (mmcf) **** (mmcf) **** (mmcf) **** (mmcf) **** (mmcf) **** (mmcf) **** (mmcf) **** (mmcf) **** (mmcf)
At December 31, 2021 62,761 33,370 96,132 62,761 33,370 96,132 — — — — — —
Discoveries — — — — — — — — — — — —
Extensions & Improved Recovery^(5)^ 3,360 5,163 8,523 3,360 5,163 8,523 — — — — — —
Technical Revisions^(6)^ (17,388) (7,658) (25,046) (17,388) (7,658) (25,046) — — — — — —
Acquisitions^(7)^ — — — — — — — — — — — —
Dispositions — — — — — — — — — — — —
Economic Factors^(8)^ 988 2,928 3,916 988 2,928 3,916 — — — — — —
Production (2,626) — (2,626) (2,626) — (2,626) — — — — — —
At December 31, 2022 **** 47,095 **** 33,803 **** 80,898 **** 47,095 **** 33,803 **** 80,898 **** — **** — **** — **** — **** — **** —

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
United States ​ Natural Gas Liquids ​ BOE
Proved Probable P+P ^(1) (2)^ ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P
Factors **** (mbbl) **** (mbbl) **** (mbbl) **** (mboe) **** (mboe) **** (mboe)
At December 31, 2021 7,939 4,323 12,262 41,134 29,180 70,315
Discoveries — — — — — —
Extensions & Improved Recovery^(5)^ 409 640 1,049 3,225 3,914 7,140
Technical Revisions^(6)^ (1,749) (568) (2,316) (8,861) (5,442) (14,302)
Acquisitions^(7)^ — — — — — —
Dispositions — — — — — —
Economic Factors^(8)^ 126 371 496 736 1,257 1,993
Production (401) — (401) (1,901) — (1,901)
At December 31, 2022 **** 6,324 **** 4,765 **** 11,089 **** 34,335 **** 28,910 **** 63,244

​

​ Vermilion Energy Inc. ■ Page 30 ■ 2022 Annual Information Form

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Total Company ​ Total Oil^(4)^ ​ Light & Medium Crude Oil ​ Heavy Crude Oil ​ Tight Oil
Proved Probable P+P ^(1) (2)^ ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P
Factors **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl)
At December 31, 2021 156,590 86,646 243,236 156,487 86,615 243,102 103 31 135 — — —
Discoveries — — — — — — — — — — — —
Extensions & Improved Recovery^(5)^ 7,552 7,810 15,362 4,384 5,666 10,050 — — — 3,168 2,144 5,312
Technical Revisions^(6)^ (6,058) (13,661) (19,719) (6,196) (13,522) (19,718) 3 (1) 3 134 (138) (4)
Acquisitions^(7)^ 3,233 4,467 7,700 190 83 273 — — — 3,043 4,384 7,427
Dispositions (26) (11) (36) (26) (11) (36) — — — — — —
Economic Factors^(8)^ 2,893 151 3,043 2,892 110 3,001 — — — 1 41 42
Production (11,975) — (11,974) (11,734) — (11,734) (5) — (5) (235) — (235)
At December 31, 2022 **** 152,208 **** 85,404 **** 237,611 **** 145,996 **** 78,942 **** 224,937 **** 101 **** 31 **** 132 **** 6,111 **** 6,431 **** 12,542

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Total Company ​ Total Gas^(4)^ ​ Conventional Natural Gas ​ Coal Bed Methane^(5)^ ​ Shale Gas
Proved Probable P+P ^(1) (2)^ ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P
Factors **** (mmcf) **** (mmcf) **** (mmcf) **** (mmcf) **** (mmcf) **** (mmcf) **** (mmcf) **** (mmcf) **** (mmcf) **** (mmcf) **** (mmcf) **** (mmcf)
At December 31, 2021 619,192 400,385 1,019,577 612,715 398,373 1,011,088 6,121 1,907 8,029 356 105 461
Discoveries — — — — — — — — — — — —
Extensions & Improved Recovery^(5)^ 98,686 77,510 176,196 22,788 18,714 41,502 — — — 75,898 58,796 134,694
Technical Revisions^(6)^ (15,802) (45,118) (60,920) (20,144) (41,045) (61,189) 645 (3) 642 3,697 (4,070) (373)
Acquisitions^(7)^ 84,303 134,261 218,563 6 3 8 — — — 84,297 134,258 218,555
Dispositions (259) (308) (567) (259) (308) (567) — — — — — —
Economic Factors^(8)^ 13,774 6,264 20,038 12,102 4,148 16,250 1,618 733 2,351 54 1,383 1,437
Production (86,936) — (86,936) (81,628) — (81,628) (917) — (917) (4,390) — (4,390)
At December 31, 2022 **** 712,958 **** 572,994 **** 1,285,952 **** 545,580 **** 379,885 **** 925,464 **** 7,467 **** 2,637 **** 10,104 **** 159,912 **** 190,472 **** 350,384

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Total Company ​ Natural Gas Liquids ​ BOE
Proved Probable P+P ^(1) (2)^ ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P
Factors **** (mbbl) **** (mbbl) **** (mbbl) **** (mboe) **** (mboe) **** (mboe)
At December 31, 2021 42,263 25,578 67,841 302,052 178,954 481,007
Discoveries — — — — — —
Extensions & Improved Recovery^(5)^ 3,331 2,533 5,864 27,330 23,261 50,592
Technical Revisions^(6)^ (945) (2,126) (3,070) (9,637) (23,306) (32,943)
Acquisitions^(7)^ 1,612 2,375 3,986 18,895 29,218 48,113
Dispositions (10) (29) (38) (78) (91) (169)
Economic Factors^(8)^ 472 429 900 5,659 1,624 7,283
Production (4,629) — (4,629) (31,093) — (31,093)
At December 31, 2022 **** 42,094 **** 28,760 **** 70,854 **** 313,128 **** 209,662 **** 522,790

​

​ Vermilion Energy Inc. ■ Page 31 ■ 2022 Annual Information Form

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
North America ​ Total Oil^(4)^ ​ Light & Medium Crude Oil ​ Heavy Crude Oil ​ Tight Oil
Proved Probable P+P ^(1) (2)^ ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P
Factors **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl)
At December 31, 2021 108,310 64,701 173,011 108,206 64,670 172,876 103 31 135 — — —
Discoveries — — — — — — — — — — — —
Extensions & Improved Recovery^(5)^ 6,950 5,366 12,317 3,782 3,222 7,005 — — — 3,168 2,144 5,312
Technical Revisions^(6)^ (3,476) (10,236) (13,713) (3,614) (10,097) (13,711) 3 (1) 3 134 (138) (4)
Acquisitions^(7)^ 3,233 4,467 7,700 190 83 273 — — — 3,043 4,384 7,427
Dispositions (26) (11) (36) (26) (11) (36) — — — — — —
Economic Factors^(8)^ 1,507 130 1,636 1,506 89 1,594 — — — 1 41 42
Production (7,204) — (7,204) (6,963) — (6,963) (5) — (5) (235) — (235)
At December 31, 2022 **** 109,293 **** 64,417 **** 173,711 **** 103,081 **** 57,956 **** 161,037 **** 101 **** 31 **** 132 **** 6,111 **** 6,431 **** 12,542

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Total Gas^(4)^ ​ Conventional Natural Gas ​ Coal Bed Methane^(5)^ ​ Shale Gas
Proved Probable P+P ^(1) (2)^ ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P
Factors **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl)
At December 31, 2021 437,991 264,776 702,767 431,514 262,764 694,277 6,121 1,907 8,029 356 105 461
Discoveries — — — — — — — — — — — —
Extensions & Improved Recovery^(5)^ 97,997 77,141 175,138 22,099 18,345 40,444 — — — 75,898 58,796 134,694
Technical Revisions^(6)^ (13,019) (36,308) (49,326) (17,360) (32,235) (49,595) 645 (3) 642 3,697 (4,070) (373)
Acquisitions^(7)^ 84,303 134,261 218,563 6 3 8 — — — 84,297 134,258 218,555
Dispositions (155) (254) (409) (155) (254) (409) — — — — — —
Economic Factors^(8)^ 7,924 5,876 13,800 6,252 3,760 10,012 1,618 733 2,351 54 1,383 1,437
Production (55,225) — (55,225) (49,917) — (49,917) (917) — (917) (4,390) — (4,390)
At December 31, 2022 **** 559,816 **** 445,492 **** 1,005,308 **** 392,437 **** 252,383 **** 644,820 **** 7,467 **** 2,637 **** 10,104 **** 159,912 **** 190,472 **** 350,384

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Natural Gas Liquids ​ BOE
Proved Probable P+P ^(1) (2)^ ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P
Factors **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl)
At December 31, 2021 42,170 25,471 67,641 223,478 134,301 357,780
Discoveries — — — — — —
Extensions & Improved Recovery^(5)^ 3,331 2,532 5,863 26,614 20,755 47,369
Technical Revisions^(6)^ (890) (2,065) (2,955) (6,536) (18,353) (24,889)
Acquisitions^(7)^ 1,612 2,375 3,986 18,895 29,218 48,113
Dispositions (10) (29) (38) (61) (82) (143)
Economic Factors^(8)^ 466 426 891 3,292 1,535 4,827
Production (4,605) — (4,605) (21,013) — (21,013)
At December 31, 2022 **** 42,074 **** 28,710 **** 70,784 **** 244,669 **** 167,376 **** 412,045

​

​ Vermilion Energy Inc. ■ Page 32 ■ 2022 Annual Information Form

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Total Oil^(4)^ ​ Light & Medium Crude Oil ​ Heavy Crude Oil ​ Tight Oil
International ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P
Factors **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl)
At December 31, 2021 48,281 21,945 70,225 48,281 21,945 70,225 — — — — — —
Discoveries — — — — — — — — — — — —
Extensions & Improved Recovery^(5)^ 601 2,444 3,046 601 2,444 3,046 — — — — — —
Technical Revisions^(6)^ (2,582) (3,424) (6,007) (2,582) (3,424) (6,007) — — — — — —
Acquisitions^(7)^ — — — — — — — — — — — —
Dispositions — — — — — — — — — — — —
Economic Factors^(8)^ 1,386 21 1,407 1,386 21 1,407 — — — — — —
Production (4,771) — (4,771) (4,771) — (4,771) — — — — — —
At December 31, 2022 **** 42,915 **** 20,986 **** 63,901 **** 42,915 **** 20,986 **** 63,901 **** — **** — **** — **** — **** — **** —

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Total Gas^(4)^ ​ Conventional Natural Gas ​ Coal Bed Methane^(5)^ ​ Shale Gas
Proved Probable P+P ^(1) (2)^ ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P
Factors **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl)
At December 31, 2021 181,201 135,609 316,810 181,201 135,609 316,810 — — — — — —
Discoveries — — — — — — — — — — — —
Extensions & Improved Recovery^(5)^ 689 369 1,058 689 369 1,058 — — — — — —
Technical Revisions^(6)^ (2,784) (8,810) (11,594) (2,784) (8,810) (11,594) — — — — — —
Acquisitions^(7)^ — — — — — — — — — — — —
Dispositions (104) (55) (158) (104) (55) (158) — — — — — —
Economic Factors^(8)^ 5,850 388 6,239 5,850 388 6,239 — — — — — —
Production (31,711) — (31,711) (31,711) — (31,711) — — — — — —
At December 31, 2022 **** 153,142 **** 127,502 **** 280,644 **** 153,142 **** 127,502 **** 280,644 **** — **** — **** — **** — **** — **** —

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Natural Gas Liquids ​ BOE
Proved Probable P+P ^(1) (2)^ ​ Proved ​ Probable ​ P+P ​ Proved ​ Probable ​ P+P
Factors **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl) **** (mbbl)
At December 31, 2021 93 107 200 78,574 44,653 123,227
Discoveries — — — — — —
Extensions & Improved Recovery^(5)^ 1 — 1 717 2,506 3,223
Technical Revisions^(6)^ (55) (61) (115) (3,101) (4,953) (8,054)
Acquisitions^(7)^ — — — — — —
Dispositions — — — (17) (9) (26)
Economic Factors^(8)^ 6 3 9 2,367 89 2,456
Production (24) — (24) (10,080) — (10,080)
At December 31, 2022 **** 21 **** 50 **** 70 **** 68,459 **** 42,286 **** 110,745

​

Notes:

(1) "Proved" reserves are those reserves that can be estimated with a high degree of certainty to be recoverable. It is likely that the actual remaining quantities recovered will exceed the estimated proved reserves.
(2) "Probable" reserves are those additional reserves that are less certain to be recovered than proved reserves. It is equally likely that the actual remaining quantities recovered will be greater or less than the sum of the estimated proved plus probable reserves.
--- ---
(3) The pricing assumptions used in the GLJ Report with respect to net present value of future net revenue (forecast) as well as the inflation rates used for operating and capital costs are set forth in “Forecast Prices used in Estimates”. GLJ is an independent qualified reserves evaluator appointed pursuant to NI 51-101.
--- ---
(4) “Total Oil” is the sum of Light Crude Oil and Medium Crude Oil, Heavy Crude Oil and Tight Oil. For reporting purposes, and “Total Gas” is the sum of Conventional Natural Gas, Coal Bed Methane and Shale Gas.
--- ---
(5) “Extensions & Improved Recovery" are additions following the Corporation's acquisition in the Montney, the extension additions were primarily driven by inventory locations in this new asset to align with the higher capital allocation Vermilion has assigned to these assets.
--- ---
(6) "Technical Revisions" are negative revisions that were predominately related to a modified capital allocation plan. Higher risk assets with lower profitability in predominantly Saskatchewan and the United States were moved out of our near term development plans from our reserves. This is due to the acquired Montney assets, which are viewed as more profitable and high-graded opportunities in the portfolio and will receive higher capital allocation.
--- ---
(7) "Acquisitions" are due to a major acquisition completed by the Corporation targeting the Montney formation, which included producing reserves and undeveloped bookings.
--- ---
(8) "Economic factors" are positive revisions that were seen in all countries with an improved market price outlook on all commodities vs prior year.
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​ Vermilion Energy Inc. ■ Page 33 ■ 2022 Annual Information Form

​

Undeveloped reserves

​

​

Proved undeveloped reserves are those reserves expected to be recovered from known accumulations where a significant expenditure (for example, when compared to the cost of drilling a well) is required to render them capable of production. These reserves have a 90% probability of being recovered. Vermilion's current plan is to develop these reserves in the following three years. The pace of development of these reserves is influenced by many factors, including but not limited to, the outcomes of yearly drilling and reservoir evaluations, changes in commodity pricing, changes in capital allocations, changing technical conditions, regulatory changes and impact of future acquisitions and dispositions. As new information becomes available these reserves are reviewed and development plans are revised accordingly.

​

Probable undeveloped reserves are those reserves expected to be recovered from known accumulations where a significant expenditure (for example, when compared to the cost of drilling a well) is required to render them capable of production. These reserves have a 50% probability of being recovered. Vermilion's current plan is to develop these reserves over the next five years. In general, development of these reserves requires additional evaluation data to increase the probability of success to a level that favourably ranks the project against other projects in Vermilion's inventory. This increases the timeline for the development of these reserves. This timetable may be altered depending on outside market forces, changes in capital allocations and impact of future acquisitions and dispositions.

​

Timing of initial undeveloped reserves assignment

​

​

Undeveloped Reserves Attributed in Current Year

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Light Crude Oil & Medium Crude Oil ​ Heavy Crude Oil ​ Tight Oil ​ Conventional Natural Gas
​ ​ First ​ ​ ​ First ​ ​ ​ First ​ ​ ​ First ​ ​
​ Attributed ^(1)^ Booked (mbbl) Attributed ^(1)^ Booked (mbbl) Attributed ^(1)^ Booked (mbbl) Attributed ^(1)^ Booked (mbbl)
Proved ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
2020 ​ 4,750 ​ 50,919 ​ — ​ 43 ​ — ​ — ​ 20,851 ​ 128,421
2021 ​ 6,645 ​ 60,945 ​ — ​ 85 ​ — ​ — ​ 21,123 ​ 134,249
2022 ​ 3,212 ​ 54,984 ​ — ​ 84 ​ 3,623 ​ 3,623 ​ 13,303 ​ 117,067
Probable ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
2020 ​ 2,835 ​ 55,447 ​ — ​ 68 ​ — ​ — ​ 39,583 ​ 256,151
2021 ​ 1,551 ​ 56,057 ​ — ​ 24 ​ — ​ — ​ 27,387 ​ 226,458
2022 ​ 5,564 ​ 52,006 ​ — ​ 25 ​ 6,060 ​ 6,060 ​ 18,380 ​ 213,689

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Shale Gas **** Coal Bed Methane **** Natural Gas Liquids **** Total Oil Equivalent
​ ​ First ​ Booked ​ First ​ Booked ​ First ​ Booked ​ First ​ Booked
​ **** Attributed^(1)^ **** (mmcf) **** Attributed^(1)^ **** (mmcf) **** Attributed^(1)^ **** (mmcf) **** Attributed^(1)^ **** (mboe)
Proved
2020 — ​ — 446 875 14,708 9,100 87,147
2021 — ​ — 376 2,118 14,502 12,284 97,970
2022 100,205 100,205 — 428 3,652 15,437 29,405 110,411
Probable
2020 — — — 121 2,413 17,866 11,845 116,092
2021 ​ — — 109 2,155 16,293 8,271 110,136
2022 179,177 179,177 — 120 6,384 19,451 50,934 143,041

​

Note:

(1) “First Attributed” refers to reserves first attributed at year-end of the corresponding fiscal year.

​

Future development costs

​

​

The table below sets out the future development costs deducted in the estimation of future net revenue attributable to total proved reserves and total proved plus probable reserves (using forecast prices and costs). The future development cost estimates disclosed below are associated with reserves as evaluated by GLJ. The future development cost estimates will differ from the costs ultimately incurred by Vermilion due to a number of factors, including costs incurred for properties that do not have associated reserves as evaluated by GLJ and economic factors that may alter development pace and project selection.

​ Vermilion Energy Inc. ■ Page 34 ■ 2022 Annual Information Form

Vermilion expects to source its capital expenditure requirements from internally generated cash flow and, as appropriate, from Vermilion’s existing credit facility or equity or debt financing. It is anticipated that costs of funding the future development costs will not impact development of its properties or Vermilion’s reserves or future net revenue.

​

​ ​ ​ ​ ​
​ **** Total Proved **** Total Proved Plus Probable
($M) ​ Estimated Using Forecast Prices and Costs^(1)^ ​ Estimated Using Forecast Prices and Costs ^(1)^
Australia ​ ​
2023 — —
2024 — 57,788
2025 — —
2026 — —
2027 — —
Remainder — —
Australia total for all years undiscounted **** — **** 57,788
Canada
2023 287,862 345,300
2024 367,183 539,121
2025 297,636 486,570
2026 163,739 307,267
2027 60,577 145,037
Remainder 81,576 110,415
Canada total for all years undiscounted **** 1,258,573 **** 1,933,710
CEE
2023 4,688 4,688
2024 — —
2025 — —
2026 — —
2027 — —
Remainder — —
CEE total for all years undiscounted **** 4,688 **** 4,688
France
2023 15,986 26,889
2024 23,919 41,976
2025 12,931 23,408
2026 17,006 42,656
2027 11,442 22,035
Remainder — 9,147
France total for all years undiscounted **** 81,284 **** 166,112
Germany
2023 9,512 15,327
2024 14,776 27,234
2025 3,056 11,850
2026 13,985 17,969
2027 2,729 21,476
Remainder — —
Germany for all years undiscounted **** 44,058 **** 93,857

​ Vermilion Energy Inc. ■ Page 35 ■ 2022 Annual Information Form

​ ​ ​ ​ ​
​ **** Total Proved **** Total Proved Plus Probable
($M) ​ Estimated Using Forecast Prices and Costs^(1)^ ​ Estimated Using Forecast Prices and Costs ^(1)^
Ireland ​ ​ ​ ​
2023 ​ 4,245 4,245
2024 ​ 2,852 2,852
2025 ​ 7,527 7,527
2026 ​ 7,692 29,121
2027 ​ 312 312
Remainder ​ — —
Ireland total for all years undiscounted ​ 22,627 44,056
Netherlands ​ ​ ​ ​
2023 ​ 14,020 16,273
2024 ​ 1,486 1,486
2025 ​ 447 12,874
2026 ​ 328 14,657
2027 ​ 237 11,342
Remainder ​ 275 21,016
Netherlands total for all years undiscounted ​ 16,792 77,648
United States ​ ​ ​ ​
2023 ​ 30,002 62,458
2024 ​ 48,231 48,231
2025 ​ 78,624 105,904
2026 ​ 76,166 143,945
2027 ​ 29,760 106,407
Remainder ​ — —
United States total for all years undiscounted ​ 262,783 466,946
Total Company ​ ​ ​ ​
2023 ​ 366,315 475,181
2024 ​ 458,446 718,688
2025 ​ 400,220 648,133
2026 ​ 278,916 555,616
2027 ​ 105,057 306,609
Remainder ​ 81,851 140,579
Total for all years undiscounted ​ 1,690,806 2,844,805
North America ​ ​ ​ ​
2023 ​ 317,864 407,758
2024 ​ 415,414 587,352
2025 ​ 376,260 592,474
2026 ​ 239,905 451,213
2027 ​ 90,337 251,443
Remainder ​ 81,576 110,415
North America total for all years undiscounted ​ 1,521,356 2,400,656
International ​ ​ ​ ​
2023 ​ 48,452 67,422
2024 ​ 43,032 131,336
2025 ​ 23,960 55,659
2026 ​ 39,010 104,403
2027 ​ 14,720 55,166
Remainder ​ 275 30,163
International total for all years undiscounted ​ 169,450 444,149

​

Note:

(1) The pricing assumptions used in the GLJ Report with respect to net present value of future net revenue (forecast) as well as the inflation rates used for operating and capital costs are detailed in “Forecast Prices used in Estimates”.

​ Vermilion Energy Inc. ■ Page 36 ■ 2022 Annual Information Form

Crude oil and natural gas properties and wells

​

​

The following table sets forth the number of wells (based on wellbores) in which Vermilion held a working interest as at December 31, 2022:

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Crude Oil ​ Natural Gas
​ ​ Producing ​ Non-Producing^(4)^ ​ Producing ​ Non-Producing^(4)^
​ **** Gross Wells^(2)^ **** Net Wells^(3)^ **** Gross Wells^(2)^ **** Net Wells^(3)^ **** Gross Wells^(2)^ **** Net Wells^(3)^ **** Gross Wells^(2)^ **** Net Wells^(3)^
Canada ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Alberta 386 271 129 89 495 354 ​ 313 219
Saskatchewan 2,608 1,621 2,491 1,617 — — 23 15
British Columbia 11 11 3 3 3 3 ​ 3 3
Total Canada 3,005 1,903 2,623 1,710 498 357 339 237
Australia ^(1)^ 22 22 1 1 — — ​ 1 1
Croatia — — — — — — 2 2
France 307 301 125 124 — — ​ 3 3
Germany 70 58 116 95 24 13 6 3
Ireland ^(1)^ — — — — 6 1 ​ — —
Netherlands — — — — 99 41 ​ 125 71
Hungary — — — — 2 1 ​ — —
United States 169 162 74 70 — — — —
Total Vermilion 3,573 2,446 2,939 1,999 629 413 476 317
North America 3,174 2,064 2,697 1,780 498 357 339 237
International 399 381 242 220 131 57 ​ 137 80

​

Notes:

(1) Wells for Australia and Ireland are located offshore.
(2) "Gross" refers to the total wells in which Vermilion has an interest, directly or indirectly.
--- ---
(3) "Net" refers to the total wells in which Vermilion has an interest, directly or indirectly, multiplied by the percentage working interest owned by Vermilion, directly or indirectly, therein.
--- ---
(4) Non-producing wells include wells which are capable of producing, but which are currently not producing, and are re-evaluated with respect to future commodity prices, proximity to facility infrastructure, design of future exploration and development programs, and access to capital.
--- ---

​

Costs incurred

​

​

The following table summarizes the capital expenditures made by Vermilion on oil and gas properties for the year ended December 31, 2022:

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ Acquisition Costs for Proved ​ Acquisition Costs for Unproved ​ Exploration ​ Development ​ Total
(M) Properties **** Properties **** Costs **** Costs **** Costs
Australia — ​ — ​ — ​ 95,173 ​ 95,173
Canada 531,348 ​ — ​ — ​ 275,203 ​ 806,551
Croatia — — 15,132 ​ 15,132
France — — 2 44,250 44,252
Germany 3,857 — 1,070 25,087 30,014
Hungary — — 7,352 331 7,683
Ireland 2,726 — — 3,030 5,756
Netherlands 707 — 23 21,629 22,359
Slovakia — — 182 ​ 183
United States 1,075 — — 63,353 64,428
Total 539,713 — 23,761 528,056 1,091,531
North America 532,423 — — 338,556 870,979
International 7,290 — 23,761 189,500 220,552

All values are in US Dollars.

​ Vermilion Energy Inc. ■ Page 37 ■ 2022 Annual Information Form

Acreage

​

​

The following table summarizes the acreage for the year ended December 31, 2022:

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Developed ^(1)^ ​ Undeveloped ​ Total
​ **** Gross ^(2)^ **** Net ^(3)^ **** Gross ^(2)^ **** Net ^(3)^ **** Gross ^(2)(4)^ **** Net ^(3)(4)^
Australia 20,164 20,164 39,389 39,389 59,552 59,552
Canada 796,648 649,892 384,237 325,777 1,180,885 975,668
Croatia 6,487 6,487 968,888 968,888 975,374 975,374
France 258,125 248,873 106,993 106,993 365,117 355,865
Germany 107,351 54,626 1,549,929 706,817 1,657,280 761,443
Hungary 1,220 1,220 613,405 613,405 614,625 614,625
Ireland 7,200 1,440 — — 7,200 1,440
Netherlands 158,582 63,311 1,445,624 781,097 1,604,206 844,409
Slovakia — — 97,907 48,954 97,907 48,954
United States 83,759 69,731 65,284 52,955 149,043 122,686
Total 1,439,534 1,115,743 5,271,655 3,644,273 6,711,189 4,760,016
North America 880,407 719,623 449,521 378,732 1,329,928 1,098,354
International 559,129 396,121 4,822,135 3,265,543 5,381,261 3,661,662

​

Notes:

(1) “Developed” means the acreage assigned to productive wells based on applicable regulations.
(2) “Gross” means the total acreage in which Vermilion has a working interest, directly or indirectly.
--- ---
(3) “Net” means the total acreage in which Vermilion has a working interest, directly or indirectly, multiplied by the percentage working interest of Vermilion.
--- ---
(4) When determining gross and net acreage for two or more leases covering the same lands but different rights, the acreage is reported for each lease. Where there are multiple discontinuous rights in a single lease, the acreage is reported only once.
--- ---

​ Vermilion Energy Inc. ■ Page 38 ■ 2022 Annual Information Form

Exploration and development activities

​

​

The following table sets forth the number of development and exploration wells which Vermilion completed during its 2022 financial year:

​

​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Exploration Wells ​ Development Wells
​ **** Gross^(1)^ **** Net^(2)^ **** Gross^(1)^ **** Net^(2)^
Australia ​ ​ ​ ​ ​ ​
Oil — — 2.0 2.0
Gas — — — —
Dry Holes — — — —
Total Australia — — 2.0 2.0
Canada ​ ​ ​ ​ ​ ​
Oil — — 61.0 38.1
Gas — — 21.0 18.0
Service ​ — ​ — ​ — ​ —
Dry Holes — — — —
Total Canada — — 82.0 56.1
Croatia ​ ​ ​ ​ ​ ​
Oil — — — —
Gas — — — —
Dry holes 1.0 1.0 — —
Total Croatia 2.0 2.0 — —
France ​ ​ ​ ​ ​ ​
Oil — — — —
Gas — — — —
Dry Holes — — — —
Total France — — — —
Germany ​ ​ ​ ​ ​ ​
Oil 1.0 — 2.0 —
Gas — — — —
Service — — — —
Dry Holes — — — —
Total Germany 1.0 — 2.0 —
Hungary ​ ​ ​ ​ ​ ​
Oil — — — —
Gas — — — —
Dry Holes 3.0 3.0 — —
Total Hungary 3.0 3.0 — —
Ireland ​ ​ ​ ​ ​ ​
Oil — — — —
Gas — — — —
Dry Holes — — — —
Total Ireland — — — —
Netherlands ​ ​ ​ ​ ​ ​
Oil — — — —
Gas — — — —
Dry Holes — — — —
Total Netherlands — — — —
United States ​ ​ ​ ​ ​ ​
Oil — — 6.0 5.8
Gas — — — —
Dry Holes — — — —
Total United States — — 6.0 5.8

​ Vermilion Energy Inc. ■ Page 39 ■ 2022 Annual Information Form

​ ​ ​ ​ ​ ​ ​ ​ ​
Total Company **** ​ **** ​ **** ​ **** ​
Oil ​ 1.0 — 71.0 45.9
Gas ​ — — 21.0 18.0
Service ​ — ​ — ​ — ​ —
Dry Holes ​ 4.0 4.0 — —
Total Company ​ 6.0 5.0 92.0 63.9
North America ​ ​ ​ ​ ​ ​ ​ ​
Oil ​ — — 67.0 43.9
Gas ​ — — 21.0 18.0
Service ​ — ​ — ​ — ​ —
Dry Holes ​ — — — —
Total North America ​ — — 88.0 61.9
International ​ ​ ​ ​ ​ ​ ​ ​
Oil ​ 1.0 — 4.0 2.0
Gas ​ — — — —
Service ​ — — — —
Dry Holes ​ 4.0 4.0 — —
Total International ​ 6.0 5.0 4.0 2.0

​

Notes:

(1) "Gross" refers to the total wells in which Vermilion has an interest, directly or indirectly.
(2) "Net" refers to the total wells in which Vermilion has an interest, directly or indirectly, multiplied by the percentage working interest owned by Vermilion, directly or indirectly therein.
--- ---

​

Properties with no attributed reserves

​

​

The following table sets out Vermilion's properties with no attributed reserves as at December 31, 2022:

​

​ ​ ​ ​ ​
Country **** Gross Acres^(1)^ **** Net Acres^(2)^
Australia 39,389 39,389
Canada 384,237 325,777
Croatia 968,888 968,888
France 106,993 106,993
Germany 1,549,929 706,817
Hungary 613,405 613,405
Ireland — —
Netherlands 1,445,624 781,097
Slovakia 97,907 48,954
United States 65,284 52,955
Total **** 5,271,655 **** 3,644,273
North America 449,521 378,732
International 4,822,135 3,265,543

​

Notes:

(1) "Gross" refers to the total acres in which Vermilion has an interest, directly or indirectly.
(2) "Net" refers to the total acres in which Vermilion has an interest, directly or indirectly, multiplied by the percentage working interest owned by Vermilion, directly or indirectly therein.
--- ---

​

Vermilion expects its rights to explore, develop, and exploit approximately 94,009 (89,806 net) acres in Canada, 466,770 (466,770 net) acres in Croatia, 322,437 (322,437 net) acres in Hungary, 49,395 (27,167 net) acres in France, and 5,414 (4,202 net) acres in the United States to expire within one year, unless the Company initiates the capital activity necessary to retain the rights. Work commitments on these lands are categorized as seismic acquisition, geophysical studies, or well commitments. No such rights are expected to expire within one year for Australia, Germany, Ireland, the Netherlands, and Slovakia. Vermilion currently has no material work commitments in Australia, Canada, Ireland, the Netherlands and the United States. Vermilion's work commitments with respect to its European lands held are estimated to be $43.0 million in the next year.

​

Vermilion’s properties with no attributed reserves do not have any significant abandonment and reclamation costs. All properties with no attributed reserves do not have high expected development or operating costs or contractual sales obligations to produce and sell at substantially lower prices than could be realized.

​ Vermilion Energy Inc. ■ Page 40 ■ 2022 Annual Information Form

Production estimates

​

​

The following table sets forth the volume of production estimated for the year ended December 31, 2023 as reflected in the estimates of gross proved reserves and gross proved plus probable reserves in the GLJ Report:

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Light Crude Oil & ​ ​ ​ ​ ​ Conventional ​ Shale ​ Coal Bed ​ Natural **** Gas ​ ​
​ ​ Medium Crude Oil ​ Heavy Crude Oil ​ Tight Oil ​ Natural Gas ​ Natural **** Gas ​ Methane ​ Liquids ​ BOE
​ **** (bbl/d) **** (bbl/d) **** (bbl/d) **** (mcf/d) **** (mcf/d) **** (mcf/d) **** (bbl/d) **** (boe/d)
Australia
Proved 3,684 — — — — — — 3,684
Probable 123 — — — — — — 123
Proved Plus Probable **** 3,807 **** — **** — **** — **** — **** — **** — **** 3,807
Canada
Proved 18,518 12 1,699 113,520 36,317 2,207 10,876 56,446
Probable 2,372 — 83 17,057 613 43 1,385 6,792
Proved Plus Probable **** 20,891 **** 12 **** 1,781 **** 130,577 **** 36,931 **** 2,251 **** 12,261 **** 63,238
CEE
Proved — — — 575 — — — 96
Probable — — — 25 — — — 4
Proved Plus Probable **** — **** — **** — **** 600 **** — **** — **** — **** 100
France
Proved 7,940 — — — — — — 7,940
Probable 212 — — — — — — 212
Proved Plus Probable **** 8,152 **** — **** — **** — **** — **** — **** — **** 8,152
Germany
Proved 1,757 — — 24,210 — — — 5,792
Probable 648 — — 1,209 — — — 849
Proved Plus Probable **** 2,405 **** — **** — **** 25,419 **** — **** — **** — **** 6,641
Ireland
Proved — — — 21,241 — — — 3,540
Probable — — — 281 — — — 47
Proved Plus Probable **** — **** — **** — **** 21,522 **** — **** — **** — **** 3,587
Netherlands
Proved — — — 24,310 — — 18 4,070
Probable — — — 2,859 — — 3 479
Proved Plus Probable **** — **** — **** — **** 27,169 **** — **** — **** 21 **** 4,549
United States
Proved 3,190 — — 8,244 — — 1,104 5,668
Probable 1,436 — — 1,588 — — 251 1,951
Proved Plus Probable **** 4,626 **** — **** — **** 9,832 **** — **** — **** 1,354 **** 7,619
Corporate
Proved 35,090 12 1,699 192,100 36,317 2,207 11,998 87,236
Probable 4,791 — 83 23,019 613 43 1,638 10,458
Proved Plus Probable **** 39,881 **** 12 **** 1,781 **** 215,120 **** 36,931 **** 2,251 **** 13,637 **** 97,694
North America
Proved 21,709 12 1,699 121,764 36,317 2,207 11,980 62,114
Probable 3,808 — 83 18,645 613 43 1,635 8,743
Proved Plus Probable **** 25,517 **** 12 **** 1,781 **** 140,409 **** 36,931 **** 2,251 **** 13,615 **** 70,857
International ​
Proved 13,381 — — 70,336 — — 18 25,122
Probable 983 — — 4,374 — — 3 1,715
Proved Plus Probable **** 14,364 **** — **** — **** 74,710 **** — **** — **** 21 **** 26,837

​ Vermilion Energy Inc. ■ Page 41 ■ 2022 Annual Information Form

Production history

​

​

The following table sets forth certain information in respect of production, product prices received, royalties paid, production costs, and netbacks received by Vermilion for each quarter of its most recently completed financial year:

​

​ ​ ​ ​ ​ ​ ​ ​
​ Three Months Ended March 31, 2022 **** Three Months Ended June 31, 2022 **** Three Months Ended September 31, 2022 **** Three Months Ended December 31, 2022
Australia ​ ​ ​ ​ ​ ​ ​
Average Daily Production ​ ​ ​ ​ ​ ​ ​
Light Crude Oil and Medium Crude Oil (bbl/d) 3,888 2,465 4,763 4,847
Conventional Natural Gas (mmcf/d) — — — —
Natural Gas Liquids (bbl/d) — — — —
Average Net Prices Received
Light Crude Oil and Medium Crude Oil (/bbl) 147.16 166.75 155.29 139.95
Conventional Natural Gas (/mcf) — — — —
Natural Gas Liquids (/bbl) — — — —
Royalties
Light Crude Oil and Medium Crude Oil (/bbl) — — — —
Conventional Natural Gas (/mcf) — — — —
Natural Gas Liquids (/bbl) — — — —
Production Costs
Light Crude Oil and Medium Crude Oil (/bbl) 39.59 56.38 40.98 31.23
Conventional Natural Gas (/mcf) — — — —
Natural Gas Liquids (/bbl) — — — —
Netback Received
Light Crude Oil and Medium Crude Oil (/bbl) 107.57 110.37 114.31 108.72
Conventional Natural Gas (/mcf) — — — —
Natural Gas Liquids (/bbl) — — — —
Canada
Average Daily Production
Light Crude Oil and Medium Crude Oil (bbl/d) 15,980 17,042 16,835 17,448
Conventional Natural Gas (mmcf/d) 140.55 143.94 145.04 146.81
Natural Gas Liquids (bbl/d) 12,178 12,028 11,074 10,804
Average Net Prices Received
Light Crude Oil and Medium Crude Oil (/bbl) 110.21 135.64 113.83 104.48
Conventional Natural Gas (/mcf) 4.82 7.15 6.31 5.96
Natural Gas Liquids (/bbl) 74.29 82.82 71.02 68.13
Royalties
Light Crude Oil and Medium Crude Oil (/bbl) 16.25 19.47 17.69 14.65
Conventional Natural Gas (/mcf) 0.50 0.52 0.71 0.16
Natural Gas Liquids (/bbl) 16.90 15.65 17.74 13.17
Transportation
Light Crude Oil and Medium Crude Oil (/bbl) 1.54 1.75 1.74 1.91
Conventional Natural Gas (/mcf) 0.20 0.25 0.29 0.36
Natural Gas Liquids (/bbl) 1.17 1.24 1.14 1.19
Production Costs ​ ​ ​ ​
Light Crude Oil and Medium Crude Oil (/bbl) 8.99 8.87 10.37 10.53
Conventional Natural Gas (/mcf) 1.23 1.19 1.66 1.41
Natural Gas Liquids (/bbl) 6.85 6.26 6.82 6.52
Netback Received
Light Crude Oil and Medium Crude Oil (/bbl) 83.43 105.54 84.04 77.38
Conventional Natural Gas (/mcf) 2.89 5.19 3.65 4.03
Natural Gas Liquids (/bbl) 49.37 59.67 45.31 47.25

All values are in US Dollars.

​ Vermilion Energy Inc. ■ Page 42 ■ 2022 Annual Information Form

​ ​ ​ ​ ​ ​ ​ ​
​ Three Months Ended **** Three Months Ended **** Three Months Ended **** Three Months Ended
​ March 31, 2022 ​ June 31, 2022 ​ September 31, 2022 ​ December 31, 2022
France
Average Daily Production
Light Crude Oil and Medium Crude Oil (bbl/d) 8,389 8,126 6,818 7,247
Conventional Natural Gas (mmcf/d) — — — —
Natural Gas Liquids (bbl/d) — — — —
Average Net Prices Received ​ ​ ​ ​
Light Crude Oil and Medium Crude Oil (/bbl) 133.41 141.80 135.49 119.68
Conventional Natural Gas (/mcf) — — — —
Natural Gas Liquids (/bbl) — — — —
Royalties ​ ​ ​ ​
Light Crude Oil and Medium Crude Oil (/bbl) 12.53 16.30 15.51 14.27
Conventional Natural Gas (/mcf) — — — —
Natural Gas Liquids (/bbl) — — — —
Transportation ​ ​ ​ ​
Light Crude Oil and Medium Crude Oil (/bbl) 6.84 8.02 7.28 7.05
Conventional Natural Gas (/mcf) — — — —
Natural Gas Liquids (/bbl) — — — —
Production Costs ​ ​ ​ ​
Light Crude Oil and Medium Crude Oil (/bbl) 21.58 21.12 21.57 19.41
Conventional Natural Gas (/mcf) — — — —
Natural Gas Liquids (/bbl) — — — —
Netback Received ​ ​ ​ ​
Light Crude Oil and Medium Crude Oil (/bbl) 92.46 96.36 91.13 78.95
Conventional Natural Gas (/mcf) — — — —
Natural Gas Liquids (/bbl) — — — —
Germany ​ ​ ​ ​
Average Daily Production ​ ​ ​ ​
Light Crude Oil and Medium Crude Oil (bbl/d) 1,158 1,331 1,764 1,481
Conventional Natural Gas (mmcf/d) 26.95 25.36 26.54 25.86
Natural Gas Liquids (bbl/d) — — — —
Average Net Prices Received ​ ​ ​ ​
Light Crude Oil and Medium Crude Oil (/bbl) 128.15 140.17 134.17 114.67
Conventional Natural Gas (/mcf) 33.98 35.45 62.13 43.24
Natural Gas Liquids (/bbl) — — — —
Royalties ​ ​ ​ ​
Light Crude Oil and Medium Crude Oil (/bbl) 2.07 3.20 2.65 2.64
Conventional Natural Gas (/mcf) 2.00 2.05 1.79 2.52
Natural Gas Liquids (/bbl) — — — —
Transportation ​ ​ ​ ​
Light Crude Oil and Medium Crude Oil (/bbl) 11.08 8.86 8.25 13.67
Conventional Natural Gas (/mcf) 0.30 0.46 0.53 0.61
Natural Gas Liquids (/bbl) — — — —
Production Costs ​ ​ ​ ​
Light Crude Oil and Medium Crude Oil (/bbl) 25.43 21.93 15.77 17.53
Conventional Natural Gas (/mcf) 2.43 3.64 2.94 4.42
Natural Gas Liquids (/bbl) — — — —
Netback Received ​ ​ ​ ​
Light Crude Oil and Medium Crude Oil (/bbl) 89.57 106.18 107.50 80.83
Conventional Natural Gas (/mcf) 29.25 29.30 56.87 35.69
Natural Gas Liquids (/bbl) — — — —

All values are in US Dollars.

​ Vermilion Energy Inc. ■ Page 43 ■ 2022 Annual Information Form

​ ​ ​ ​ ​ ​ ​ ​
​ Three Months Ended March 31, 2022 **** Three Months Ended June 31, 2022 **** Three Months Ended September 31, 2022 **** Three Months Ended December 31, 2022
Hungary
Average Daily Production
Light Crude Oil and Medium Crude Oil (bbl/d) — — — —
Conventional Natural Gas (mmcf/d) 0.34 0.64 0.63 0.67
Natural Gas Liquids (bbl/d) — — — —
Average Net Prices Received
Light Crude Oil and Medium Crude Oil (/bbl) — — — —
Conventional Natural Gas (/mcf) 30.79 43.18 64.42 59.43
Natural Gas Liquids (/bbl) — — — —
Royalties
Light Crude Oil and Medium Crude Oil (/bbl) — — — —
Conventional Natural Gas (/mcf) 9.00 8.13 27.64 18.78
Natural Gas Liquids (/bbl) — — — —
Production Costs
Light Crude Oil and Medium Crude Oil (/bbl) — — — —
Conventional Natural Gas (/mcf) 11.20 7.56 8.53 6.80
Natural Gas Liquids (/bbl) — — — —
Netback Received
Light Crude Oil and Medium Crude Oil (/bbl) — — — —
Conventional Natural Gas (/mcf) 19.59 35.62 55.89 52.63
Natural Gas Liquids (/bbl) — — — —
Ireland
Average Daily Production
Light Crude Oil and Medium Crude Oil (bbl/d) — — — —
Conventional Natural Gas (mmcf/d) 30.26 27.93 25.74 26.04
Natural Gas Liquids (bbl/d) — — — —
Average Net Prices Received
Light Crude Oil and Medium Crude Oil (/bbl) — — — —
Conventional Natural Gas (/mcf) 38.20 20.96 43.20 27.02
Natural Gas Liquids (/bbl) — — — —
Royalties
Light Crude Oil and Medium Crude Oil (/bbl) — — — —
Conventional Natural Gas (/mcf) — — — —
Natural Gas Liquids (/bbl) — — — —
Transportation
Light Crude Oil and Medium Crude Oil (/bbl) — — — —
Conventional Natural Gas (/mcf) 0.36 0.37 0.38 0.31
Natural Gas Liquids (/bbl) — — — —
Production Costs
Light Crude Oil and Medium Crude Oil (/bbl) — — — —
Conventional Natural Gas (/mcf) 1.41 1.31 1.99 1.96
Natural Gas Liquids (/bbl) — — — —
Netback Received
Light Crude Oil and Medium Crude Oil (/bbl) — — — —
Conventional Natural Gas (/mcf) 36.43 19.28 40.83 24.75
Natural Gas Liquids (/bbl) — — — —

All values are in US Dollars.

​ Vermilion Energy Inc. ■ Page 44 ■ 2022 Annual Information Form

​ ​ ​ ​ ​ ​ ​ ​
​ Three Months Ended March 31, 2022 **** Three Months Ended June 31, 2022 **** Three Months Ended September 31, 2022 **** Three Months Ended December 31, 2022
Netherlands
Average Daily Production
Light Crude Oil and Medium Crude Oil (bbl/d) — — — —
Conventional Natural Gas (mmcf/d) 39.03 35.22 29.15 27.41
Natural Gas Liquids (bbl/d) 84 60 74 49
Average Net Prices Received
Light Crude Oil and Medium Crude Oil (/bbl) — — — —
Conventional Natural Gas (/mcf) 37.57 38.91 68.73 47.47
Natural Gas Liquids (/bbl) 78.45 110.99 139.28 (6.47)
Royalties ​
Light Crude Oil and Medium Crude Oil (/bbl) — — — —
Conventional Natural Gas (/mcf) — — — 0.20
Natural Gas Liquids (/bbl) — — — —
Production Costs
Light Crude Oil and Medium Crude Oil (/bbl) — — — —
Conventional Natural Gas (/mcf) 2.98 3.43 4.92 4.45
Natural Gas Liquids (/bbl) — — — —
Netback Received
Light Crude Oil and Medium Crude Oil (/bbl) — — — —
Conventional Natural Gas (/mcf) 34.59 35.48 63.81 42.82
Natural Gas Liquids (/bbl) 78.45 110.99 139.28 (6.47)
United States
Average Daily Production
Light Crude Oil and Medium Crude Oil (bbl/d) 2,675 2,846 2,824 3,282
Conventional Natural Gas (mmcf/d) 7.56 6.74 7.03 7.45
Natural Gas Liquids (bbl/d) 1,080 998 1,066 1,254
Average Net Prices Received
Light Crude Oil and Medium Crude Oil (/bbl) 112.64 140.04 119.80 114.41
Conventional Natural Gas (/mcf) 4.48 6.76 8.33 6.00
Natural Gas Liquids (/bbl) 46.97 55.89 52.01 49.72
Royalties
Light Crude Oil and Medium Crude Oil (/bbl) 28.04 37.16 5.33 5.87
Conventional Natural Gas (/mcf) 1.40 1.86 2.42 1.85
Natural Gas Liquids (/bbl) 1.19 1.12 1.38 1.51
Transportation
Light Crude Oil and Medium Crude Oil (/bbl) 0.61 0.34 0.15 0.17
Conventional Natural Gas (/mcf) — — — —
Natural Gas Liquids (/bbl) 0.24 0.12 0.05 0.06
Production Costs
Light Crude Oil and Medium Crude Oil (/bbl) 8.04 9.28 11.46 13.01
Conventional Natural Gas (/mcf) 1.87 1.92 2.61 2.75
Natural Gas Liquids (/bbl) 3.25 3.25 4.33 4.97
Netback Received
Light Crude Oil and Medium Crude Oil (/bbl) 75.95 93.26 102.86 95.36
Conventional Natural Gas (/mcf) 1.21 2.98 3.30 1.40
Natural Gas Liquids (/bbl) 42.28 51.40 46.24 43.18

All values are in US Dollars.

​ Vermilion Energy Inc. ■ Page 45 ■ 2022 Annual Information Form

​ ​ ​ ​ ​ ​ ​ ​
​ Three Months Ended March 31, 2022 **** Three Months Ended June 31, 2022 **** Three Months Ended September 31, 2022 **** Three Months Ended December 31, 2022
Total Company
Average Daily Production
Light Crude Oil and Medium Crude Oil (bbl/d) 32,091 31,811 33,003 34,305
Conventional Natural Gas (mmcf/d) 244.69 239.83 234.12 234.23
Natural Gas Liquids (bbl/d) 13,341 13,086 12,213 12,107
Average Net Prices Received
Light Crude Oil and Medium Crude Oil (/bbl) 117.80 139.02 116.79 124.76
Conventional Natural Gas (/mcf) 17.41 16.50 24.68 17.43
Natural Gas Liquids (/bbl) 72.10 80.89 69.77 65.93
Royalties
Light Crude Oil and Medium Crude Oil (/bbl) 27.14 33.59 29.95 26.57
Conventional Natural Gas (/mcf) 0.56 0.60 0.79 0.51
Natural Gas Liquids (/bbl) 18.09 16.77 19.12 14.68
Transportation Costs
Light Crude Oil and Medium Crude Oil (/bbl) 2.29 2.60 2.45 2.44
Conventional Natural Gas (/mcf) 0.20 0.24 0.28 0.33
Natural Gas Liquids (/bbl) 0.95 1.07 0.91 0.86
Production Costs
Light Crude Oil and Medium Crude Oil (/bbl) 13.17 13.03 14.04 14.50
Conventional Natural Gas (/mcf) 1.70 1.83 2.29 2.21
Natural Gas Liquids (/bbl) 5.48 5.36 5.20 5.12
Netback Received
Light Crude Oil and Medium Crude Oil (/bbl) 75.19 89.80 70.34 81.24
Conventional Natural Gas (/mcf) 14.95 13.83 21.32 14.38
Natural Gas Liquids (/bbl) 47.58 57.69 44.55 45.27
North America
Average Daily Production
Light Crude Oil and Medium Crude Oil (bbl/d) 18,655 19,888 19,659 20,730
Conventional Natural Gas (mmcf/d) 148.11 150.68 152.07 154.26
Natural Gas Liquids (bbl/d) 13,258 13,026 12,140 12,058
Average Net Prices Received
Light Crude Oil and Medium Crude Oil (/bbl) 110.55 136.27 114.69 106.05
Conventional Natural Gas (/mcf) 4.80 7.13 6.41 5.96
Natural Gas Liquids (/bbl) 71.27 80.75 70.11 66.94
Royalties
Light Crude Oil and Medium Crude Oil (/bbl) 17.94 22.00 19.71 17.27
Conventional Natural Gas (/mcf) 0.55 0.58 0.79 0.24
Natural Gas Liquids (/bbl) 16.44 15.48 17.64 13.30
Transportation Costs
Light Crude Oil and Medium Crude Oil (/bbl) 2.97 3.14 2.83 2.92
Conventional Natural Gas (/mcf) 0.19 0.24 0.28 0.34
Natural Gas Liquids (/bbl) 1.80 2.02 2.14 2.35
Production Costs
Light Crude Oil and Medium Crude Oil (/bbl) 8.85 8.93 10.53 10.92
Conventional Natural Gas (/mcf) 1.26 1.22 1.70 1.47
Natural Gas Liquids (/bbl) 6.56 6.03 6.60 6.36
Netback Received
Light Crude Oil and Medium Crude Oil (/bbl) 80.79 102.20 81.62 74.94
Conventional Natural Gas (/mcf) 2.80 5.09 3.64 3.90
Natural Gas Liquids (/bbl) 46.48 57.22 43.74 44.93

All values are in US Dollars.

​ Vermilion Energy Inc. ■ Page 46 ■ 2022 Annual Information Form

​ ​ ​ ​ ​ ​ ​ ​
​ Three Months Ended March 31, 2022 **** Three Months Ended June 31, 2022 **** Three Months Ended September 31, 2022 **** Three Months Ended December 31, 2022
International
Average Daily Production
Light Crude Oil and Medium Crude Oil (bbl/d) 13,436 11,923 13,345 13,575
Conventional Natural Gas (mmcf/d) 96.58 89.15 82.05 79.97
Natural Gas Liquids (bbl/d) 83 60 74 49
Average Net Prices Received
Light Crude Oil and Medium Crude Oil (/bbl) 127.86 143.62 119.88 153.32
Conventional Natural Gas (/mcf) 36.75 32.33 58.55 39.54
Natural Gas Liquids (/bbl) 77.09 109.83 140.33 (3.14)
Royalties
Light Crude Oil and Medium Crude Oil (/bbl) 7.37 11.31 8.75 7.77
Conventional Natural Gas (/mcf) 0.59 0.64 0.79 1.04
Natural Gas Liquids (/bbl) — — — —
Transportation Costs
Light Crude Oil and Medium Crude Oil (/bbl) 5.43 6.94 5.39 5.99
Conventional Natural Gas (/mcf) 0.20 0.25 0.29 0.30
Natural Gas Liquids (/bbl) — — — —
Production Costs
Light Crude Oil and Medium Crude Oil (/bbl) 27.12 28.50 27.73 23.43
Conventional Natural Gas (/mcf) 2.36 2.86 3.39 3.65
Natural Gas Liquids (/bbl) — — — —
Netback Received ​
Light Crude Oil and Medium Crude Oil (/bbl) 87.94 96.87 78.01 116.13
Conventional Natural Gas (/mcf) 33.59 28.59 54.09 34.55
Natural Gas Liquids (/bbl) 77.09 109.83 140.33 (3.14)

All values are in US Dollars.

​

Marketing

​

​

The nature of Vermilion’s operations results in exposure to fluctuations in commodity prices, interest rates, and foreign currency exchange rates. Vermilion monitors and, when appropriate, uses derivative financial instruments to manage its exposure to these fluctuations. All transactions of this nature entered into by Vermilion are related to an underlying financial position or to future crude oil and natural gas production. Vermilion does not use derivative financial instruments for speculative purposes. Vermilion has not obtained collateral or other security to support its financial derivatives as management reviews the creditworthiness of its counterparties prior to entering into derivative contracts.

​

During the normal course of business, Vermilion may also enter into fixed price arrangements to sell a portion of its production or purchase commodities for operational use.

​

Vermilion’s outstanding risk management positions as at December 31, 2022 are summarized in Supplemental Table 2: Hedges, included in the Company’s 2022 Management’s Discussion and Analysis, dated March 8, 2023, available on SEDAR at www.sedar.com, under Vermilion’s SEDAR profile.

​

​ Vermilion Energy Inc. ■ Page 47 ■ 2022 Annual Information Form

Directors and Officers

​

As at January 31, 2023, the directors and officers of Vermilion beneficially owned, or controlled or directed, directly or indirectly, 991,619 common shares representing approximately 0.6% of the issued and outstanding common shares.

​

Set forth below is certain information respecting the current directors and officers of Vermilion. References to Vermilion in the following tables for dates prior to the Conversion Arrangement refer to VRL and to the Company following the date of the Conversion Arrangement.

​

Board of Directors

​

​

Vermilion’s Board of Directors currently consists of ten directors. The directors are nominated by the Company and elected annually by Shareholders and hold office until the next annual meeting of Shareholders, or until their successors are elected or appointed.

​

​ ​ ​ ​ ​ ​ Year First ​ ​
Name and ​ ​ ​ ​ ​ Elected or ​ ​
Municipality of ​ ​ ​ ​ ​ Appointed ​ ​
Residence **** Committee(s) **** Office Held **** as Director **** Principal Occupation During the Past Five Years
Robert Michaleski<br>Calgary, Alberta<br>Canada ​ (1) (3) (5) ​ Director ​ 2016 ​ 2000 to 2020, Director of Pembina Pipeline Corporation<br><br>​<br><br>2013 to 2018, Director of United Way of Calgary and Area, a non-profit organization<br><br>​<br><br>Since 2012, Director of Essential Energy Services Ltd., a public oilfield services company<br><br>​<br><br>Since 2003, Director of Coril Holdings Ltd., a private investment company
Dion Hatcher<br>Calgary, Alberta<br>Canada ​ ​ ​ President &<br>Chief<br>Executive<br>Officer and<br>Director ​ 2023 ​ Since March 2023, President & Chief Executive Officer of Vermilion<br><br>​<br><br>January 2022 to March 2023, President of Vermilion<br><br>​<br><br>November 2020 to December 2021 Vice President North America of Vermilion<br><br>​<br><br>March 2016 to November 2020, Vice President Canada Business Unit of Vermilion
James J. Kleckner Jr.<br>Edwards, Colorado<br>USA ​ (7) (9) ​ Director ​ 2021 ​ Since 2021, Director of Great Western Petroleum, a public oil and gas company<br><br>​<br><br>2019 to 2021, Director of Parsley Energy, a public oil and gas company<br><br>​<br><br>2018 to 2020, Chief Executive Officer of Jagged Peak Energy Inc., a public oil and gas company<br><br>​<br><br>2018 to 2020, Director of Jagged Peak Energy Inc., a public oil and gas company<br><br>​<br><br>2016 to 2019, Director of Delonex Energy Ltd., a private oil and gas company
Carin S. Knickel<br>Golden, Colorado<br>USA ​ (4) (7) (11) ​ Director ​ 2018 ​ Since 2015, Director of Hudbay Minerals, Inc., a public mining company<br><br>​<br><br>2015 to 2020, Director of Whiting Petroleum, a public oil and gas company<br><br>​<br><br>Since 2014, Director of National MS Society (Colorado/Wyoming Chapter), a non-profit organization
Stephen Larke<br>Calgary, Alberta<br>Canada ​ (3) (5) (10) ​ Director ​ 2017 ​ Since 2020, Director of Headwater Exploration Inc., a public oil and gas company<br><br>​<br><br>Since 2019, Director of Topaz Energy Corp., a public energy company<br><br>​<br><br>2017 to 2018, Operating Partner and Advisory Board Member, Azimuth Capital Management, a private equity fund
Timothy R. Marchant<br>Calgary, Alberta<br>Canada ​ (6) (9) (11) ​ Director ​ 2010 ​ Since 2022, Director of Vaalco Energy Inc., a public oil and gas company<br><br>​<br><br>2020 to 2022, Director of TransGlobe Energy Corporation, a public oil and gas company<br><br>​<br><br>Since 2015, Director, Valeura Energy Inc., a public oil and gas company<br><br>​<br><br>2013 to 2022, Director of Cub Energy Inc., a public oil and gas company<br><br>​<br><br>Since 2009, Adjunct Professor of Strategy and Energy Geopolitics, Haskayne School of Business
William Roby<br>Katy, Texas<br>USA ​ (7) (8) (11) ​ Director ​ 2017 ​ Since 2020, Director of California Resources Corp, a public oil and gas company<br><br>​<br><br>Since 2015, Chief Executive Officer, Shepherd Energy, LLC., a private energy efficiency services company

Vermilion Energy Inc. ■ Page 48 ■ 2022 Annual Information Form

​ ​ ​ ​ ​ ​ Year First ​ ​
Name and ​ ​ ​ ​ ​ Elected or ​ ​
Municipality of ​ ​ ​ ​ ​ Appointed ​ ​
Residence **** Committee(s) **** Office Held **** as Director **** Principal Occupation During the Past Five Years
Manjit Sharma<br>Toronto, Ontario<br>Canada ​ (2) (5) ​ Director ​ 2021 ​ Since 2023, Director of TransAlta Corporation, a public utilities company<br><br>​<br><br>Since 2022, Director of Finning International Inc., a public machinery manufacturing company<br><br>​<br><br>Since 2020, Director of Export Development Canada, a financial services company<br><br>​<br><br>2020 to 2021, Chief Financial Officer of WSP Canada, a civil engineering company<br><br>​<br><br>2019 to 2021, Audit Committee of Ontario Chamber of Commerce, a charitable organization<br><br>​<br><br>2016 to 2019, Chief Financial Officer of GE Canada, an industrial engineering company<br><br>​<br><br>2013 to 2020, Audit and Investment Committee YMCA Greater Toronto, a charitable organization
Myron Stadnyk<br>Calgary, Alberta Canada ​ (7) (9) ​ Director ​ 2022 ​ 2013 to 2020, Chief Executive Officer of ARC Resources Ltd.<br><br>​<br><br>Since 2018, Director of Prairie Sky Royalty Ltd.<br><br>​<br><br>Since 2020, Director of Crescent Point Energy Corp.<br><br>​<br><br>Since 2018, Chair of the University of Saskatchewan Engineering Trust
Judy Steele<br>Halifax, Nova Scotia<br>Canada ​ (3) (5) (11) ​ Director ​ 2021 ​ Since 2012, President and Chief Operating Officer of Emera Energy, an energy marketing and trading company<br>​<br><br>Since 2017, Director of Canadian Blood Services, a non-profit organization

​

Committees:

^(1)^ Chairman (Independent)
^(2)^ Audit Committee Chair (Independent)
--- ---
^(3)^ Audit Committee Member (Independent)
--- ---
^(4)^ Governance and Human Resources Committee Chair (Independent)
--- ---
^(5)^ Governance and Human Resources Committee Member (Independent)
--- ---
^(6)^ Health, Safety and Environment Committee Chair (Independent)
--- ---
^(7)^ Health, Safety and Environment Committee Member (Independent)
--- ---
^(8)^ Independent Reserves Committee Chair (Independent)
--- ---
^(9)^ Independent Reserves Committee Member (Independent)
--- ---
^(10)^ Sustainability Committee Chair (Independent)
--- ---
^(11)^ Sustainability Committee Member (Independent)
--- ---

​ Vermilion Energy Inc. ■ Page 49 ■ 2022 Annual Information Form

Officers

​

​

Name and ​ Office Held ​ Principal Occupation During the Past Five Years
Municipality of ​ ​ ​ ​
Residence **** ​ **** ​
Dion Hatcher<br>Calgary, Alberta<br>Canada ​ President<br>& Chief Executive Officer ​ Since March 2023, President & Chief Executive Officer of Vermilion<br><br>​<br><br>January 2022 to March 2023, President of Vermilion<br><br>​<br><br>November 2020 to December 2021, Vice President North America of Vermilion<br><br>​<br><br>March 2016 to November 2020, Vice President Canada Business Unit of Vermilion
Lars Glemser<br>Calgary, Alberta<br>Canada ​ Vice President<br>& Chief Financial Officer ​ Since April 2018, Vice President and Chief Financial Officer of Vermilion<br><br>​<br><br>January 2018 to April 2018, Director, Finance of Vermilion<br><br>​<br><br>June 2015 to January 2018, Finance Professional of Vermilion
Terry Hergott<br>Calgary, Alberta<br>Canada ​ Vice President <br>Marketing ​ Since April 2012, Vice President, Marketing of Vermilion
Yvonne Jeffery<br>Calgary, Alberta<br>Canada ​ Vice President<br>Sustainability ​ May 2021, Vice President, Sustainability of Vermilion<br><br>​<br><br>August 2020 to May 2021, Director, Sustainability of Vermilion<br><br>​<br><br>April 2018 to August 2020, Manager Communications, Community Investment and Sustainability of Vermilion<br><br>​<br><br>November 2015 to March 2018, Team Lead, Communications, Community Investment and Sustainability of Vermilion
Darcy Kerwin<br>Calgary, Alberta<br>Canada ​ Vice President<br>International & HSE ​ Since November 2020, Vice President, International & HSE of Vermilion<br><br>​<br><br>September 2020 to November 2020, Vice President, Strategic Planning of Vermilion<br><br>​<br><br>February 2018 to September 2020, Managing Director, Ireland Business Unit of Vermilion<br><br>​<br><br>March 2014 to February 2018, Managing Director, France Business Unit of Vermilion
Bryce Kremnica<br>Calgary, Alberta<br>Canada ​ Vice President<br>North America ​ Since November 2021, Vice President, North America of Vermilion<br><br>​<br><br>May 2014 to November 2021, Director, Field Operations Canada Business Unit of Vermilion
Geoff MacDonald<br>Calgary, Alberta<br>Canada ​ Vice President<br>Geosciences ​ Since November 2021, Vice President, Geosciences of Vermilion<br><br>​<br><br>March 2019 to November 2021, Chief Geoscientist of Vermilion<br><br>​<br><br>August 2015 to March 2019, Vice President, Exploration of Velvet Energy, a private oil and gas company
Kyle Preston<br>Calgary, Alberta<br>Canada ​ Vice President<br>Investor Relations ​ Since July 2019, Vice President, Investor Relations of Vermilion<br><br>​<br><br>May 2016 to July 2019, Director, Investor Relations of Vermilion
Averyl Schraven<br>Calgary, Alberta<br>Canada ​ Vice President<br><br>People and Culture ​ Since November 2021, Vice President, People & Culture of Vermilion<br><br>​<br><br>December 2020 to November 2021, Director, People and Culture of Vermilion<br><br>​<br><br>February 2014 to December 2020, Manager, Global Human Resources Services of Vermilion
Jenson Tan<br>Calgary, Alberta<br>Canada ​ Vice President<br><br>Business Development ​ Since October 2017, Vice President, Business Development of Vermilion<br><br>​<br><br>July 2016 to October 2017, Director, Business Development of Vermilion
Gerard Schut<br>Den Haag<br>The Netherlands ​ Vice President<br><br>European Operations ​ Since July 2012, Vice President, European Operations of Vermilion
Robert J. Engbloom, KC<br>Calgary, Alberta<br>Canada ​ Corporate Secretary ​ Since January 2015, counsel with Norton Rose Fulbright Canada LLP, a law firm

​

​

​ Vermilion Energy Inc. ■ Page 50 ■ 2022 Annual Information Form

Description of Capital Structure

​

Credit ratings

​

​

Credit ratings affect the Company's ability to obtain short-term and long-term financing and the cost of such financing. Additionally, the ability of the Company to engage in certain collateralized business activities on a cost effective basis depends on the Company's credit ratings. A reduction in the credit rating of the Company or the Company's debt or a negative change in the Company's ratings outlook could adversely affect the Company's cost of financing and its access to sources of liquidity and capital. In addition, changes in credit ratings may affect the Company's ability to enter into ordinary course hedging arrangements or contracts with customers and suppliers.

​

Credit ratings are intended to provide investors with an independent measure of the credit quality of an issuer of securities. The credit ratings accorded to the Senior Unsecured Notes and the Company are not recommendations to purchase, hold or sell such securities and are not a comment upon the market price of the Company's securities or their suitability for a particular investor. There is no assurance that any rating will remain in effect for any given period of time or that any rating will not be revised or withdrawn entirely by a rating agency in the future if, in its judgment, circumstances so warrant. A revision or withdrawal of a credit rating could have a material adverse effect on the pricing or liquidity of the Senior Unsecured Notes or the common shares in any secondary markets. Vermilion does not undertake any obligation to maintain the ratings or to advise holders of the Senior Unsecured Notes or the common shares of any change in ratings. Each agency's rating should be evaluated independently of any other agency's rating.

​

As at March 8, 2023, Vermilion had the following credit ratings from S&P Global Ratings ("S&P"), Moody's Investors Service (“Moody’s”), and Fitch Ratings (“Fitch”):

​

Rating Agency **** Company Rating **** Outlook **** Senior Unsecured Notes
S&P ^(1)^ ​ B+ ^(1)^ ​ Stable ​ BB- ^(4)^
Moody's ^(2)^ ​ B1 ^(2)^ ​ Stable ​ B3 ^(5)^
Fitch ^(3)^ ​ BB- ^(3)^ ​ Negative ​ BB- ^(6)^

​

Notes:

^(1)^ S&P rates long-term corporate credit ratings by rating categories ranging from a high of "AAA" to a low of "D". Ratings from AA to CCC may be modified by the addition of a plus (+) or minus (-) sign to show relative standing within the major rating categories. In addition, S&P may add a rating outlook of “positive”, “negative” or “stable” which assesses the potential direction of a long-term credit rating over the intermediate term (typically six months to two years). An obligor rated “B” is within the sixth highest of the ten categories, and is characterized by S&P as more vulnerable in the near term than obligors rated "BB", but has the capacity to meet its financial commitments on the obligation. However, it faces major ongoing uncertainties and exposure to adverse business, financial or economic conditions, which could lead to the obligor’s inadequate capacity to meet its financial commitments.
^(2)^ Moody's corporate family ratings are on a rating scale that ranges from Aaa to C, which represents the highest to lowest opinions of creditworthiness. Moody’s appends numerical modifiers 1, 2, and 3 to each generic rating classification from Aa through Caa, with 3 indicating a ranking in the lower end of the generic rating category. A rating of B1 by Moody’s is within the sixth highest of nine categories. An obliger rated B1 is considered non-investment grade speculative and is subject to high credit risk.
--- ---
^(3)^ Fitch’s corporate credit rating categories range from “investment grade“ for those with ratings of “AAA” to “BBB”, and “speculative grade” for those with “BB” to “D” ratings. Modifiers may be used by Fitch within these rating categories, either (+) or (-), appended to a rating to indicate relative status within the major rating categories. Rating outlooks may be provided to direct where a rating may potentially move within the next year or two, and fall under four outlooks: “positive”, “stable”, “negative”, or “evolving”. A “BB-” rating for an obliger denotes an increased vulnerability to default risk, especially if experiencing adverse changes in economic or business conditions over time; conversely, there remains a financial or business flexibility that sustains the servicing of financial obligations.
--- ---
^(4)^ S&P rates long-term debt instruments by rating categories ranging from a high of "AAA" to a low of "D". The ratings from AA to CCC may be modified by the addition of a plus (+) or minus (-) sign to show relative standing within the major rating categories. An obligation rated "B+" is characterized as less vulnerable to nonpayment than other speculative issues. However, an obligation rated "B+" faces major ongoing uncertainties or exposure to adverse business, financial, or economic conditions, which could lead to the obligor's inadequate capacity to meet its financial commitment on the obligation. The "B" category is the sixth highest of the ten available categories.
--- ---
^(5)^ Moody’s long-term obligations ratings are on a rating scale that ranges from Aaa to C, which represents the highest to lowest opinions of creditworthiness. Moody’s appends numerical modifiers 1, 2, and 3 to each generic rating classification from Aa through Caa, with 3 indicating a ranking in the lower end of the generic rating category. A rating of B3 by Moody’s is within the sixth highest of nine categories. Obligations rated B3 are considered non-investment grade speculative and are subject to high credit risk.
--- ---
^(6)^ Fitch’s long-term debt instrument ratings are categorized from “investment grade“ for those with ratings of “AAA” to “BBB”, and “speculative grade” for those with “BB” to “D” ratings. Modifiers may be used by Fitch within these rating categories, either (+) or (-), appended to a rating to indicate relative status within the major rating categories. A “BB-” rating for an obliger denotes an increased vulnerability to default risk, especially if experiencing adverse changes in economic or business conditions over time; conversely, there remains a financial or business flexibility that sustains the servicing of financial obligations.
--- ---

​ Vermilion Energy Inc. ■ Page 51 ■ 2022 Annual Information Form

Common shares

​

​

The Company is authorized to issue an unlimited number of common shares. Each common share entitles the holder to receive notice of and to attend all meetings of Shareholders and to one vote at any such meeting. The holders of common shares are, at the discretion of the board and subject to applicable legal restrictions, entitled to receive any dividends declared by the board on the common shares. The holders of common shares are entitled to share equally in any distribution of the assets of the Company upon the liquidation, dissolution, bankruptcy or winding-up of the Company or other distribution of its assets among the Shareholders for the purpose of winding-up the Company’s affairs.

​

Awards pursuant to which a holder may receive Common Shares have been issued under certain Vermilion compensation arrangements. See Vermilion's annual financial statements as at and for the year ended December 31, 2022 (a copy of which is available on SEDAR at www.sedar.com under Vermilion’s SEDAR profile) for further details regarding the amount and value of such awards.

​

Dividend history

​

​

The Company paid a monthly dividend from January 2003 through March 2020. The dividend was suspended in April 2020 in response to the deterioration in near-term commodity prices and worsening outlook for global oil demand as a result of the COVID-19 pandemic and OPEC+ oil price war. Vermilion has a long history of paying dividends and we remain strong proponents of returning capital to Shareholders and as a result of our focus on financial strength we reinstated the dividend in the first quarter of 2022 and subsequently increased the per share amounts in both the second quarter of 2022 and the first quarter of 2023.

​

Solvency tests imposed by the ABCA on corporations for the declaration and payment of dividends must be satisfied prior to the declaration of a dividend. In addition, decisions with respect to the declaration of dividends on the common shares are made by the Board of Directors on the basis of the Company's net earnings, financial requirements, and other conditions.

​

The following table sets forth the history of Vermilion's dividend per share:

​

​ ​ ​ ​ ​ ​
Date ​ Frequency **** Dividend per unit or share
January 2003 to December 2007 ​ Monthly ​ $ 0.170
January 2008 to December 2012 ​ Monthly ​ $ 0.190
January 2013 to December 2013 ​ Monthly ​ $ 0.200
January 2014 to March 2018 ​ Monthly ​ $ 0.215
April 2018 to February 2020 ​ Monthly ​ $ 0.230
March 2020 ​ Monthly ​ $ 0.115
April 2022 to July 2022 ​ Quarterly ​ $ 0.060
August 2022 to March 2023 ​ Quarterly ​ $ 0.080
April 2023 onwards ​ Quarterly ​ $ 0.100

​

The following table outlines dividends declared per share for each of the three most recently completed financial years:

​

​ ​ ​ ​
Date **** Dividends per common share
January 2020 to March 2020 ​ $ 0.58
April 2022 to December 2022 ​ $ 0.20

​

In the first quarter of 2023, we increased the quarterly dividend 25% to $0.10 per share, aligned with our dividend policy of providing ratable increases while ensuring the annual dividend amount is sustainable at mid-cycle pricing and our continued focus on debt reduction in 2023. The dividend of $0.10 per share for Q1 2023 was declared on March 8, 2023.

​ Vermilion Energy Inc. ■ Page 52 ■ 2022 Annual Information Form

Market for Securities

​

The outstanding common shares of the Company are listed and posted for trading on the Toronto Stock Exchange ("TSX") and the New York Stock Exchange ("NYSE") under the symbol VET. The following table sets forth the closing price range and trading volume of the common shares on the TSX for the periods indicated:

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
2022 **** High **** Low **** Close **** Volume
January ​ $ 20.37 ​ $ 15.95 ​ $ 19.78 40,244,796
February ​ $ 24.03 ​ $ 19.24 ​ $ 23.70 36,577,354
March ​ $ 30.76 ​ $ 23.75 ​ $ 26.25 61,292,055
April ​ $ 29.73 ​ $ 23.11 ​ $ 25.03 36,541,960
May ​ $ 29.20 ​ $ 22.72 ​ $ 27.36 40,157,256
June ​ $ 31.80 ​ $ 21.76 ​ $ 24.50 48,202,888
July ​ $ 33.34 ​ $ 21.70 ​ $ 33.11 38,527,271
August ​ $ 39.21 ​ $ 27.86 ​ $ 35.08 39,679,590
September ​ $ 35.54 ​ $ 25.14 ​ $ 29.57 38,795,380
October ​ $ 32.63 ​ $ 27.70 ​ $ 31.79 29,259,388
November ​ $ 34.00 ​ $ 24.58 ​ $ 26.59 45,056,846
December ​ $ 27.17 ​ $ 22.92 ​ $ 23.97 23,523,479

​

​

Audit Committee Matters

​

Audit committee charter

​

​

Vermilion has established an audit committee (the "Audit Committee") to assist the board of directors in carrying out its oversight responsibilities with respect to, among other things, financial reporting, internal controls, and the external audit process of the Company. The Audit Committee Terms of Reference are set out in Schedule "C" to this annual information form.

​ Vermilion Energy Inc. ■ Page 53 ■ 2022 Annual Information Form

Composition of the Audit Committee

​

​

The following table sets forth the name of each current member of the Audit Committee, whether pursuant to applicable securities legislation, such member is considered independent, whether pursuant to applicable securities legislation, such member is considered financially literate and the relevant education and experience of such member.

​

Name **** Independent **** Financially<br><br>Literate **** Relevant Education and Experience
Manjit Sharma<br>(Chair) ​ Yes ​ Yes ​ Ms. Sharma has over 30 years of experience operating in complex global organizations across many industry sectors including power, energy, transportation, oil & gas, financial services, mining, and consulting. While Ms. Sharma most recently served as Chief Financial Officer of WSP Canada, the bulk of her career has been with GE Canada. While at GE, Ms. Sharma held a variety of progressively senior management roles, lastly as its Chief Financial Officer, her responsibilities spanned strategic planning and analysis, mergers and acquisitions, tax oversight, risk, governance, diversity and inclusion. Ms. Sharma serves as a member of the Board of Directors for Export Development Canada, Finning International Inc., TransAlta Corporation, and is a member of the GE Canada Pension Trust Investment Committee. She previously served as a Director of the BGO Prime Canadian Property Fund, the Board of GE Canada Company, the Ontario Chamber of Commerce and the YMCA of the Greater Toronto Area. Ms. Sharma was also recognized as one of Canada’s Top 100 Most Powerful Women in 2019. Ms. Sharma holds a Bachelors of Commerce degree from the University of Toronto, is a FCPA FCA, and has completed both the Institute of Corporate Directors Education Program and the Global Competent Boards Designation.
Robert Michaleski ​ Yes ​ Yes ​ Mr. Michaleski holds a Bachelor of Commerce (Honours) degree from the University of Manitoba and is a Chartered Accountant. He has over 30 years of experience in various senior management and executive capacities at Pembina Pipeline Corporation. He was Chief Executive Officer from 2000 to 2013 and also President from 2000 to 2012. He was Vice President and Chief Financial Officer from 1997 to 2000, Vice President of Finance from 1992 to 1997, Controller from 1980 to 1992, and Manager of Internal Audit from 1978 to 1980. He was a Director of Pembina from 2000 to 2020, a Director of Essential Energy Services Ltd. since 2012, and a Director of Coril Holdings Ltd. since 2003. He is a member of the Institute of Corporate Directors.
Stephen Larke ​ Yes ​ Yes ​ Mr. Larke holds a Bachelor of Commerce (Distinction) degree from the University of Calgary and is a Chartered Financial Analyst. He brings over 20 years of experience in energy capital markets, including research, sales, trading, and equity finance. From 2017 to 2018, he was Operating Partner and Advisory Board member with Azimuth Capital Management, an energy-focused private equity fund based in Calgary, Alberta. From 2005 to 2015, Mr. Larke was Managing Director and Executive Committee member with Peters & Co., an independent energy investment firm based in Calgary. From 1997 to 2005, he was Vice-President and Director with TD Newcrest, serving in the role of energy equity analyst.
Judy Steele ​ Yes ​ Yes ​ Ms. Steele has more than 35 years of experience in various energy businesses including hydro, wind, biomass and natural gas fired electrical generating facilities. Currently, Ms. Steele is the President & Chief Operating Officer of Emera Energy Inc., where she is responsible for commercial performance, operations, business growth and development, risk management, and team leadership and development. She is a member of the Emera Inc. Corporate Leadership Team and Emera’s Sustainability Management Committee and Leadership Safety Advisory Council. Prior to her current role, Ms. Steele held a variety of executive and senior management positions within Emera Inc. Ms. Steele is currently a Board member of Canadian Blood Services and a Governor of St. Francis Xavier University. She previously served as a Director and Chair of the Audit Committee for The Halifax Port Authority and was National Chair of the Canadian Breast Cancer Foundation. Ms. Steele is a recipient of the Chartered Accountant of the Year Award, from the Institute of Chartered Accountants of Nova Scotia, for outstanding community leadership

​

External audit service fees

​

​

Prior to the commencement of any work, fees for all audit and non-audit services provided by the Company’s auditors must be approved by the Audit Committee.

​

During the years ended December 31, 2022 and 2021, Deloitte LLP (PCAOB ID No. 1208), the auditors of the Company, received the following fees from the Company:

​

​ ​ ​ ​ ​ ​ ​
Item **** 2022 **** 2021
Audit fees ^(1)^ ​ $ 1,497,599 ​ $ 1,530,485
Audit-related fees ^(2)^ ​ $ 68,393 ​ $ —
Tax fees ^(3)^ ​ $ 102,385 ​ $ 80,533

​

Notes:

^(1)^ Audit fees consisted of professional services rendered by Deloitte LLP for the audit of the Company's financial statements for the years ended December 31, 2022 and 2021.
^(2)^ Audit-related fees billed by Deloitte LLP for other assurance engagements required by management or regulation.
--- ---
^(3)^ Tax fees consist of fees for tax compliance services in various jurisdictions.
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​ Vermilion Energy Inc. ■ Page 54 ■ 2022 Annual Information Form

Conflicts of Interest

​

The directors and officers of Vermilion are engaged in and will continue to engage in other activities in the oil and natural gas industry and, as a result of these and other activities, the directors and officers of Vermilion may become subject to conflicts of interest. The ABCA provides that in the event that a director has an interest in a contract or proposed contract or agreement, the director shall disclose his interest in such contract or agreement and shall refrain from voting on any matter in respect of such contract or agreement unless otherwise provided under the ABCA. To the extent that conflicts of interest arise, such conflicts will be resolved in accordance with the provisions of the ABCA.

​

As at the date hereof, Vermilion is not aware of any existing or potential material conflicts of interest between Vermilion and a director or officer of Vermilion.

​

Interest of Management and Others in Material Transactions

​

No director or officer of the Company, nor any other insider of the Company, nor their associates or affiliates has or has had, at any time within the three most recently completed financial years ending December 31, 2022, any material interest, direct or indirect, in any transaction or proposed transaction that has materially affected or would materially affect the Company.

​

Legal Proceedings

​

The Company is not party to any significant legal proceedings as of March 8, 2023.

​

Material Contracts

​

The Company has not entered into any material contracts outside its normal course of business.

​

Interests of Experts

​

As at the date hereof, principals of GLJ, the independent engineers for the Company, personally disclosed in certificates of qualification that they neither had nor expect to receive any common shares. The principals of GLJ and their employees (as a group) beneficially own less than one percent of any of the Company’s securities.

​

Deloitte LLP is the auditor of the Company and is independent within the meaning of the Rules of Professional Conduct of the Chartered Professional Accountants of Alberta.

​

Transfer Agent and Registrar

​

The transfer agent and registrar for the Company’s common shares is Odyssey Trust Company at its principal offices in Calgary, Alberta and Toronto, Ontario and Vancouver, British Columbia.

​

Risk Factors

​

The following is a summary of certain risk factors relating to the business of the Company. The following information is a summary only of certain risk factors and is qualified in its entirety by reference to, and must be read in conjunction with, the detailed information appearing elsewhere in this AIF. Additional risks and uncertainties not currently known to Vermilion that it currently views as immaterial may also materially and adversely affect its business, financial condition and/or results of operations. Shareholders and potential Shareholders should carefully consider the information contained herein and, in particular, the following risk factors.

​

Market risks

​

​

Volatility of oil and gas prices

​

The Company's reserves, financial performance, financial position, and cash flows are dependent on the prices received for oil and natural gas production. Oil and natural gas prices have fluctuated materially during recent years and are determined by supply and demand factors. Supply factors can include availability (or lack thereof) of transportation capacity and production curtailments by independent producers or by OPEC members. Vermilion Energy Inc. ■ Page 55 ■ 2022 Annual Information Form

Demand factors can be impacted by general economic conditions, supply chain requirements, environmental and other factors. Environmental and other factors include changes in weather, weather patterns, fuel conservation measures, alternative fuel requirements, increasing consumer demand for alternatives to oil and gas, and technology advances in fuel economy and energy generation devices. Shifts in supply and demand for certain commodities, products, and services may occur as climate-related risks are increasingly taken into account.

​

Constraints at processing facilities and/or on transportation

​

The Company delivers its products via gathering and processing facilities, pipeline systems, trucks, rail, and tanker. The amount of crude oi, natural gas, and natural gas liquids that the Company can produce and sell is subject to the availability, proximity, and capacity of these systems and related infrastructure. Unexpected shutdowns or curtailment of capacity of gathering and processing facilities, and pipeline systems, or an inability to secure trucks, rail, or tankers could affect the Company's production, operations, and financial results. The Company's production may flow through third party facilities which the Company does not control and these facilities may discontinue or decrease operations as result of normal course service requirements, unexpected events or otherwise. A discontinuation or decrease of operation of these third party facilities could have a material adverse effect on the Company's ability to process it's production and deliver to market. Midstream and pipeline companies may take actions to maximize their return on investment, which may in turn adversely affect producers and shippers.

​

Volatility of foreign exchange rates

​

The Company's reserves, financial performance, financial position, and cash flows are affected by prevailing foreign exchange rates. An increase in the exchange rate for the Canadian dollar versus the U.S. dollar and Euro would reduce the Canadian equivalent cash receipts for Vermilion's production. Conversely, a decrease in the exchange rate for the Canadian dollar versus the U.S. dollar and Euro would increase the Canadian equivalent cash outflows for Vermilion's operating and capital expenditures.

​

Volatility of market price of Common Shares

​

The market price of Vermilion's Common Shares may be volatile and this volatility may affect the ability of Shareholders to sell Common Shares at an advantageous price. Market price fluctuations in the common shares may be due to: the Company’s operating results or financial performance failing to meet the expectations of securities analysts or investors in any quarter; downward revision in securities analysts’ estimates; governmental regulatory action; adverse change in general market conditions or economic trends; acquisitions, dispositions or other material public announcements by the Corporation or its competitors, along with a variety of additional factors, including, without limitation, those set forth under “Forward-Looking Statements” in this AIF. In addition, the market price for securities in stock markets including Common Shares may experience significant price and trading fluctuations. These fluctuations may result in volatility in the market prices of securities that may be unrelated or disproportionate to changes in the Company's operating and financial performance.

​

Hedging arrangements

​

Vermilion may enter into agreements to fix commodity prices, interest rates, and foreign exchange rates to offset the risks affecting the business. To the extent that Vermilion engages in price risk management activities to protect the Company from unfavourable fluctuations in prices and rates, the Company may also be prevented from realizing the full benefits of favourable fluctuations in prices and rates.

​

To the extent that risk management activities and hedging strategies are employed to address these risks, the Company would also be exposed to risks associated with such activities and strategies, including: counterparty risk, settlement risk, basis risk, liquidity risk and market risk. These risks could impact or negate any benefits of risk management activities and hedging strategies.

​

In addition, commodity hedging arrangements could expose the Company to the risk of financial loss if: production falls short of the hedged volumes; there is a widening of price-basis differentials between delivery points for production and the delivery point assumed in the hedge arrangements; or a sudden unexpected event materially impacts oil and natural gas prices.

​

Operational risks

​

​

Increase in operating costs or a decline in production level

​

The Company's financial performance, financial position, and cash flows are affected by the Company's operating costs and production levels. Operating costs may increase and production levels may decline at rates greater than anticipated due to unforeseen circumstances, many of which are beyond Vermilion's control.

​ Vermilion Energy Inc. ■ Page 56 ■ 2022 Annual Information Form

Production levels may decline due to an inability for Vermilion to market oil and natural gas production. This could result from the availability, proximity and capacity of gathering systems, pipelines and processing facilities that Vermilion depends on in the jurisdictions in which it operates.

​

Operating costs could increase as a result of blowouts, environmental damage, unforeseen circumstances related to climate-change, and other unexpected and dangerous conditions which could result from a number of operating and natural hazards associated with Vermilion's operations. In addition to higher costs, Vermilion may have a potential liability to regulators and third parties as a result. Vermilion maintains liability insurance, where available, in amounts consistent with industry standards. Business interruption insurance may also be purchased for selected operations, to the extent that such insurance is commercially viable. Vermilion may become liable for damages arising from such events against which it cannot insure or against which it may elect not to insure because of high premium costs or other reasons.

​

Operator performance and payment delays

​

Continuing production from a property are dependent upon the ability of the operator of the property, and the operator may fail to perform these functions properly. Payments from production generally flow through the operator and there is a risk of delay and additional expense in receiving such revenues if the operator becomes insolvent. Although satisfactory title reviews are generally conducted in accordance with industry standards, such reviews do not guarantee or certify that a defect in the chain of title may not arise to defeat the claim of Vermilion or its subsidiaries to certain properties.

​

In addition to the usual delays in payment by purchasers of oil and natural gas to the operators of the properties, and by the operator to Vermilion, payments between any of such parties may also be delayed by restrictions imposed by lenders, delays in the sale or delivery of products, delays in the connection of wells to a gathering system, blowouts or other accidents, recovery by the operator of expenses incurred in the operation of the properties or the establishment by the operator of reserves for such expenses.

​

Weather conditions

​

Vermilion's operations may be impacted by changing weather conditions, which may include: changes in temperature extremes, changes in precipitation patterns (including drought and flooding), rising sea levels, and increased severity of extreme weather events such as cyclones or floods. These events can impact Vermilion's operations, causing shutdowns and increased costs. In the Netherlands, rising water levels could impact facilities below sea level and in Australia a severe cyclonic event could cause damage to the Company's Wandoo platform.

​

Cost of new technology

​

The oil and natural gas industry is characterized by rapid and significant technological advancements and introductions of new products and services utilizing new technologies. Other oil and natural gas companies may have greater financial, technical and personnel resources that provide them with technological advantages and may in the future allow them to implement new technologies before Vermilion does. There can be no assurance that Vermilion will be able to respond to such competitive pressures and implement such technologies on a timely basis or at an acceptable cost. One or more of the technologies currently utilized by the Company or implemented in the future may become obsolete.

​

Regulatory and political risks

​

​

Tax, royalty, and other government legislation

​

Income tax laws, royalty and other government legislation relating to the oil and gas industry in the jurisdictions in which the Company operates may change in a manner that adversely affects Vermilion.

​

Vermilion is exposed to increased taxation and royalties due to windfall taxes on profits. Windfall taxes have been substantively enacted within the European Union for oil and gas companies for 2022 and/or 2023 at a minimum rate of 33% calculated on taxable profits above a 20% increase in the average yearly taxable profits as compared to 2018 to 2021. As at December 31, 2022, windfall tax rates have been legislated at 33% in the Netherlands, Germany, and France or, in the case of Ireland, announced at 75%. There remains uncertainty on whether the announced windfall tax rate in Ireland of 75% will change upon legislation. In addition, there is uncertainty on whether windfall taxes will continue beyond 2023 or whether similar legislation could be enacted in other jurisdictions that Vermilion operates in.

​

In 2021, 136 countries and jurisdictions, including Canada, agreed to implement the Organisation for Economic Co-operation and Development’s (OECD) Pillar Two rules, effective in 2023. The proposed Pillar Two rules are designed to ensure that large multinational enterprises pay a minimum level of tax (currently agreed upon at 15%) on the income arising in each jurisdiction where they operate. The proposed rules remain subject to approval and ratification in multiple countries and jurisdictions in which Vermilion operates in.

​ Vermilion Energy Inc. ■ Page 57 ■ 2022 Annual Information Form

Government regulations

​

Vermilion's operations are governed by many levels of governments in which jurisdiction the Company operates. Vermilion is subject to laws and regulations regarding environment, health and safety issues, lease interests, taxes and royalties, among others. Failure to comply with the applicable laws can result in significant increases in costs, penalties and even losses of operating licenses. The regulatory process involved in each of the countries in which Vermilion operates is not uniform and regulatory regimes vary as to complexity, timeliness of access to, and response from, regulatory bodies and other matters specific to each jurisdiction. If regulatory approvals or permits are delayed, not obtained, or revoked, there can also be delays or abandonment of projects, decreases in production and increases in costs, and Vermilion may not be able to fully execute its strategy. Governments may also amend or create new legislation and regulatory bodies may also amend regulations or impose additional requirements which could result in reduced production and increased capital, operating and compliance costs.

​

Policy and legal risks

​

Policy actions that attempt to constrain actions that contribute to the adverse effects of climate change or policy actions that seek to promote adaptation to climate change continue to evolve. Policy changes could include implementing carbon-pricing mechanisms to reduce GHG emissions, shifting energy-efficient solutions, and promoting more sustainable land-use practices. The risks and financial impact of policy changes depend on the nature and timing of the policy change.

​

Vermilion may be exposed to increased litigation risk relating to climate change. The oil and gas industry has seen an increase in climate-related litigation claims being brought before the courts by property owners, municipalities, and public interest organizations. Some of these claims include the failure of organizations to mitigate the impacts of climate change, failure to adapt to climate change, and the insufficiency of disclosure around material financial risks. As the value of loss and damage arising from climate change increases, litigation risk will also grow.

​

Political events and terrorist attacks

​

Political events throughout the world that cause disruptions in the supply of oil affect the marketability and price of oil and natural gas acquired or discovered by Vermilion. Political developments arising in the countries in which Vermilion operates have a significant impact on the price of oil and natural gas.

​

Vermilion’s oil and natural gas properties, wells and facilities could be subject to a terrorist attack. If any of Vermilion’s properties, wells or facilities or any infrastructure on which the Company relies are the subject of a terrorist attack, such attack may have a material adverse effect on Vermilion’s financial performance, financial position, and cash flows.

​

Financing risks

​

​

Discretionary nature of dividends and share buybacks

​

The declaration and payment (including the amount thereof) of future cash dividends and the amount of share buybacks under the NCIB, if any, is subject to the discretion of the Board of Directors of the Company and may vary depending on a variety of factors and conditions, including the satisfaction of the liquidity and solvency tests under the ABCA for the declaration and payment of dividends and the amount of the Company's cash flows. The Company's cash flows may be impacted by risks affecting the Company's business including: fluctuations in commodity prices, foreign exchange and interest rates; production and sales volume levels; production costs; capital expenditure requirements; royalty and tax burdens; external financing availability, and debt service requirements.

​

Depending on these and other factors considered relevant to the declaration and payment of dividends and the authorization of share buybacks by the Board of Directors and management of the Company, the Company may change its dividend policy and (or) approach to the share buybacks from time to time. Any reduction of dividends and (or) share buybacks may adversely affect the market price or value of Common Shares.

​

Additional financing

​

Vermilion’s credit facility and any replacement credit facility may not provide sufficient liquidity. The amounts available under Vermilion's credit facility may not be sufficient for future operations, or Vermilion may not be able to obtain additional financing on attractive economic terms, if at all.

​

To the extent that external sources of capital, including the issuance of additional Common Shares, become limited or unavailable, Vermilion's ability to make the necessary capital investments to maintain or expand its oil and natural gas reserves may be impaired. To the extent the Company is required to use cash flow to finance capital expenditures or property acquisitions, the level of cash available that may be declared payable as dividends will be reduced. Vermilion Energy Inc. ■ Page 58 ■ 2022 Annual Information Form

​

Debt service

​

Vermilion may finance a significant portion of its operations through debt. Amounts paid in respect of interest and principal on debt incurred by Vermilion may impair Vermilion's ability to satisfy its other obligations. Variations in interest rates and scheduled principal repayments could result in significant changes in the amount required to be applied to debt service before payment by Vermilion of its debt obligations.

​

Lenders may be provided with security over substantially all of the assets of Vermilion and its Subsidiaries. If Vermilion becomes unable to pay its debt service charges or otherwise commits an event of default such as bankruptcy, a lender may be able to foreclose on or sell the assets of Vermilion and/or its Subsidiaries.

​

Variations in interest rates and foreign exchange rates

​

An increase in interest rates could result in a significant increase in the amount the Company pays to service debt. A decrease in the exchange rate of the Canadian dollar versus the US dollar would result in higher interest and ultimate principle payment on the Company's Senior Unsecured Notes.

​

Environmental risks

​

​

Environmental legislation

​

The oil and natural gas industry is subject to environmental regulation pursuant to local, provincial, state and federal legislation. A breach of such legislation may result in the imposition of fines, the issuance of clean up orders in respect of Vermilion or its assets, or the loss or suspension of regulatory approvals. Such legislation may include carbon taxes, enhanced emissions reporting obligations, mandates on the equipment specifications, and emissions regulations. Such legislation may be changed to impose higher standards and potentially more costly obligations on Vermilion. In addition, such legislation may inhibit Vermilion's ability to operate the Company's assets and may make it more difficult for Vermilion to compete in the acquisition of new property rights. Presently, the Company does not believe the financial impact of these regulations on capital expenditures and earnings will be material. However, the Company actively monitors and assesses its exposure to this legislation.

​

Vermilion expects to incur abandonment and reclamation costs in the ordinary course of business as existing oil and gas properties are abandoned and reclaimed. These costs may materially differ from the Company's estimates due to changes in environmental regulations.

​

Vermilion's exploration and production facilities and other operations and activities emit some amount of greenhouse gases, which may be subject to legislation regulating emissions of greenhouse gases. This may result in a requirement to reduce emissions or emissions intensity from Vermilion's operations and facilities. It is possible that future regulations may require further reductions of emissions or emissions intensity.

​

Hydraulic fracturing regulations

​

Hydraulic fracturing involves the injection of water, sand and small amounts of additives under pressure into rock formations to stimulate oil and natural gas production. Hydraulic fracturing is used to produce commercial quantities of oil and natural gas from reservoirs that were previously unproductive. Hydraulic fracturing has featured prominently in recent political, media and activist commentary on the subject of water usage and environmental damage. Any new laws, regulations or permitting requirements regarding hydraulic fracturing could lead to operational delays, increased operating costs, third party or governmental claims, and could increase Vermilion's costs of compliance and doing business as well as delay the development of oil and natural gas resources from shale formations, which are not commercial without the use of hydraulic fracturing. Restrictions on hydraulic fracturing could also reduce the amount of oil and natural gas that the Company is ultimately able to produce from its reserves, as well as increase costs.

​

With activist groups expressing concern about the impact of hydraulic fracturing on the environment and water supplies, Vermilion's corporate reputation may be negatively affected by the negative public perception and public protests against hydraulic fracturing. In addition, concerns regarding hydraulic fracturing may result in changes in regulations that delay the development of oil and natural gas resources and adversely affect Vermilion's costs of compliance and reputation. Changes in government may result in new or enhanced regulatory burdens in respect of hydraulic fracturing which could affect Vermilion's business.

​

Climate change

​

In addition to other climate-related risks discussed elsewhere in this AIF, Vermilion faces transition risks and physical risks, which are described in detail in the December 31, 2022 MD&A available on SEDAR at www.sedar.com.

​ Vermilion Energy Inc. ■ Page 59 ■ 2022 Annual Information Form

Transition risks are risks that relate to the transition to a lower-carbon economy. Transition risks impact the volatility of oil and gas prices (as consumer demand for oil and gas may decrease); environmental legislation and hydraulic fracturing regulations (which may delay or restrict the development of oil and gas); the ability to obtain additional financing (as sources of financing for oil and gas development may become more restricted); and the reliance on key personnel, management, and labour (as the workforce may transition to other sources of energy development). Practices and disclosures relating to environmental matters, including climate change, are attracting increasing scrutiny by stakeholders. Vermilion’s response to addressing environmental matters can impact the Company’s reputation and affect the Company's ability to hire and retain employees; to compete for reserve acquisitions, exploration leases, licenses and concessions; and to receive regulatory approvals required to execute operating programs.

​

Physical risks relate to the physical impact of climate change, which can be event driven (acute) or longer-term shifts (chronic) in climate patterns. Physical risks can have financial implications for the Company, such as direct damage to assets and indirect impacts from production disruptions. Physical risks may also increase Vermilion's operating costs.

​

Acquisition and expansion risks

​

​

Competition

​

Vermilion actively competes for reserve acquisitions, exploration leases, licenses, concessions and skilled industry personnel with a substantial number of other oil and gas companies, some of which have significantly greater financial resources than Vermilion. Vermilion's competitors include major integrated oil and natural gas companies and numerous other independent oil and natural gas companies and individual producers and operators.

​

Vermilion's ability to successfully bid on and acquire additional property rights, to discover reserves, to participate in drilling opportunities and to identify and enter into commercial arrangements with customers will be dependent upon developing and maintaining close working relationships with its future industry partners and joint operators and its ability to select and evaluate suitable properties and to consummate transactions in a highly competitive environment.

​

International operations and future geographical/industry expansion

​

The operations and expertise of Vermilion's management are currently focused primarily on oil and natural gas production, exploration and development in three geographical regions, North America, Europe and Australia. In the future Vermilion may acquire or move into new industry related activities, enter into new geographical areas, or acquire different energy related assets. These actions may result in unexpected risks or alternatively, significantly increase the Company's exposure to one or more existing risk factors.

​

Acquisition assumptions

​

When making acquisitions, Vermilion estimates the future performance of the assets to be acquired. These estimates are subject to inherent risks associated with predicting the future performance of those assets. These estimates may not be realized over time. As such, assets acquired may not possess the value Vermilion attributed to them.

​

Failure to realize anticipated benefits of prior acquisitions

​

Vermilion may complete one or more acquisitions for various strategic reasons including to strengthen its position in the oil and natural gas industry and to create the opportunity to realize certain benefits. In order to achieve the benefits of any future acquisitions, Vermilion will be dependent upon its ability to successfully consolidate functions and integrate operations, procedures and personnel in a timely and efficient manner and to realize the anticipated growth opportunities and synergies from combining the acquired assets and operations with those of the Company. The integration of acquired assets and operations requires the dedication of management effort, time and resources, which may divert management's focus and resources from other strategic opportunities and from operational matters during the process. The integration process may result in the disruption of ongoing business and customer relationships that may adversely affect Vermilion's ability to achieve the anticipated benefits of such prior acquisitions.

​

Reserve estimates

​

​

Reserves and estimated future net revenue to be derived from reserves are estimates and have been independently evaluated by GLJ. The estimation of reserves is a complex process and requires significant judgment. Actual production and ultimate reserves will vary from those estimates and these variations may be material.

​

Assumptions incorporated into the estimation of reserves are based on information available when the estimate was prepared. These assumptions are subject to change and many are beyond the Company's control. These assumptions include: initial production rates; production decline rates; ultimate Vermilion Energy Inc. ■ Page 60 ■ 2022 Annual Information Form

recovery of reserves; timing and amount of capital expenditures; marketability of production; future prices of crude oil and natural gas; operating costs; well abandonment costs; royalties, taxes, and other government levies that may be imposed over the producing life of the reserves.

​

In addition, estimates of reserves that may be developed and produced in the future are often based on methods other than actual production history, including: volumetric calculations, probabilistic methods, and upon analogy to similar types of reserves. Estimates based on these methods are generally less reliable than those based on actual production history. Subsequent evaluation of the same reserves based upon production history will result in variations, which may be material, in the estimated reserves. As such, reserve estimates may require revision based on actual production experience.

​

The present value of estimated future net revenue referred to in this annual information form should not be construed as the fair market value of estimated crude oil and natural gas reserves attributable to the Company's properties. The estimated discounted future revenue from reserves are based upon price and cost estimates which may vary from actual prices and costs and such variance could be material. Actual future net revenue will also be affected by factors such as the amount and timing of actual production, supply and demand for crude oil and natural gas, curtailments or increases in consumption by purchasers and changes in governmental regulations and taxation.

​

Other risks

​

​

Cyber security

​

Vermilion manages cyber security risk by ensuring appropriate technologies, processes and practices are effectively designed and implemented to help prevent, detect and respond to threats as they emerge and evolve. The primary risks to Vermilion include, loss of data, destruction or corruption of data, compromising of confidential customer or employee information, leaked information, disruption of business, theft or extortion of funds, regulatory infractions, loss of competitive advantage and damage to the Company's reputation. Vermilion relies upon a variety of advanced controls as protection from such attacks including:

​

a) Enterprise class firewall infrastructure, secure network architecture and anti-malware defense systems to protect against network intrusion, malware infection and data loss.
b) Regularly conducted comprehensive third party reviews and vulnerability assessments to ensure that information technology systems are up-to-date and properly configured, to reduce security risks arising from outdated or misconfigured systems and software.
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c) Disaster recovery planning, ongoing monitoring of network traffic patterns to identify potential malicious activities or attacks.
--- ---

​

Incident response processes are in place to isolate and control potential attacks. Data backup and recovery processes are in place to minimize risk of data loss and resulting disruption of business. Through ongoing vigilance and regular employee awareness, Vermilion has not experienced a cyber security event of a material nature in the last three years. As it is difficult to quantify the significance of such events, cyber attacks such as, security breaches of company, customer, employee, and vendor information, as well as hardware or software corruption, failure or error, telecommunications system failure, service provider error, intentional or unintentional personnel actions, malicious software, attempts to gain unauthorized access to data and other electronic security breaches that could lead to disruptions in systems, unauthorized release of confidential or otherwise protected information and the corruption of data, may in certain circumstances be material and could have an adverse effect on Vermilion’s business, financial condition and results of operations. As result of the unpredictability of the timing, nature and scope of disruptions from such attacks, Vermilion could potentially be subject to production downtimes, operational delays, the compromising of confidential or otherwise protected information, destruction or corruption of data, security breaches, other manipulation or improper use of its systems and networks or financial losses, any of which could have a material adverse effect on Vermilion’s competitive position, financial condition or results of operations.

​

Accounting adjustments

​

The presentation of financial information in accordance with IFRS requires that management apply certain accounting policies and make certain estimates and assumptions which affect reported amounts in Vermilion’s consolidated financial statements. The accounting policies may result in non-cash charges to net income and write-downs of net assets in the consolidated financial statements and such adjustments may be viewed unfavourably by the market and may result in an inability to borrow funds or a decline in price of Common Shares.

​

Ineffective internal controls

​

Effective internal controls are necessary for Vermilion to provide reliable financial reports and to help prevent fraud. Although the Company has undertaken and will undertake a number of procedures in order to help ensure the reliability of its financial reports, including those that may be imposed on Vermilion under Canadian Securities Laws and applicable U.S. federal and state securities laws, Vermilion cannot be certain that such measures will ensure that the Company will maintain adequate control over financial processes and reporting. Failure to implement required new or improved controls, or difficulties encountered in their implementation, could harm Vermilion's results of operations or cause the Company to fail to meet its reporting obligations. Additionally, implementing and monitoring effective internal controls can be costly. If Vermilion or its independent auditors Vermilion Energy Inc. ■ Page 61 ■ 2022 Annual Information Form

discover a material weakness, the disclosure of that fact, even if quickly remedied, could reduce the market's confidence in Vermilion's consolidated financial statements and may result in a decline in the price of Common Shares.

​

Reliance on key personnel, management, and labour

​

Vermilion's success depends in large measure on certain key personnel. The loss of the services of such key personnel may have a material adverse effect on the Company's business, financial condition, results of operations and prospects. Vermilion does not have any key person insurance in effect. The contributions of Vermilion's existing management team to immediate and near term operations are likely to be of central importance. In addition, the labour force in certain areas in which the Company operates is limited and the competition for qualified personnel in the oil and natural gas industry is intense. Vermilion expects that similar projects or expansions will proceed in the same area during the same time frame as the Company's projects. Vermilion's projects require experienced employees, and such competition may result in increases in compensation paid to such personnel or in a lack of qualified personnel. There can be no assurance that the Company will be able to continue to attract and retain all personnel necessary for the development and operation of the business.

​

Potential conflicts of interest

​

Circumstances may arise where members of the board of directors or officers of Vermilion are directors or officers of companies which compete with Vermilion. No assurances can be given that opportunities identified by such persons will be provided to Vermilion.

​

Ukraine War

​

During 2022, Russian military forces invaded Ukraine resulting in a war between the two countries. The ongoing conflict between countries has impacted the supply of oil and gas from the region and has resulted in countries throughout the world imposing financial and trade sanctions against Russia which have had macroeconomic effects.

​

The risks disclosed in the Risk Factors section above may be exacerbated as a result of the Ukraine war, including: market risks including volatility of oil and gas prices, volatility of foreign exchange rates, volatility of market price of common shares, hedging arrangements; regulatory and political risks including tax, royalty, and other government legislation; financing risks including additional financing, debt service, variations in interest rates and foreign exchange rates; acquisition and expansion risks including international operations and future geographical/industry expansion, acquisition assumptions, failure to realize anticipated benefits of prior acquisitions.

​

COVID-19

​

COVID-19 has continued to result in varied actions by governments worldwide, impacting global oil and gas markets. The actions taken by these governments have typically included, but is not limited to travel bans, mandatory and self-imposed quarantines and isolations, social distancing, and the closing of non-essential businesses which may have significant negative effects on economies, including a substantial decline in crude oil and natural gas demand.

​

The following risks disclosed in the Risk Factors section above may be exacerbated as a result of the COVID-19 pandemic: market risks related to the volatility of oil and gas prices, volatility of foreign exchange rates, volatility of the market price of common shares, and hedging arrangements; operational risks related to increasing operating costs or declines in production levels, operator performance and payment delays, and government regulations; financing risks related to the ability to obtain additional financing, ability to service debt, and variations in interest rates and foreign exchanges rates; and other risks related to cyber-security as our workforce continues to work part time through remote connections, accounting adjustments, effectiveness of internal controls, and reliance on key personnel, management, and labour.

​ Vermilion Energy Inc. ■ Page 62 ■ 2022 Annual Information Form

Additional Information

​

Additional information relating to the Company may be found on SEDAR at www.sedar.com under Vermilion’s SEDAR profile. Additional information related to the remuneration and indebtedness of the directors and officers of the Company, and the principal holders of common shares and Rights to purchase common shares and securities authorized for issuance under the Company's equity compensation plans, where applicable, are contained in the information circular of the Company in respect of its most recent annual meeting of Shareholders involving the election of directors. Additional financial information is provided in the Company's audited financial statements and management's discussion and analysis for the year ended December 31, 2022.

​

​ Vermilion Energy Inc. ■ Page 63 ■ 2022 Annual Information Form

Appendix A

​

REPORT ON RESERVES DATA BY INDEPENDENT QUALIFIED RESERVES EVALUATOR OR AUDITOR (FORM 51-101F2)

​

To the Board of Directors of Vermilion Energy Inc. (the "Company"):

​

1. We have evaluated the Company’s reserves data as at December 31, 2022. The reserves data are estimates of proved reserves and probable reserves and related future net revenue as at December 31, 2022, estimated using forecast prices and costs.
2. The reserves data are the responsibility of the Company’s management. Our responsibility is to express an opinion on the reserves data based on our evaluation.
--- ---
3. We carried out our evaluation in accordance with standards set out in the Canadian Oil and Gas Evaluation Handbook as amended from time to time (the "COGE Handbook") maintained by the Society of Petroleum Evaluation Engineers (Calgary Chapter).
--- ---
4. Those standards require that we plan and perform an evaluation to obtain reasonable assurance as to whether the reserves data are free of material misstatement. An evaluation also includes assessing whether the reserves data are in accordance with principles and definitions presented in the COGE Handbook.
--- ---
5. The following table shows the net present value of future net revenue (before deduction of income taxes) attributed to proved plus probable reserves, estimated using forecast prices and costs and calculated using a discount rate of 10 percent, included in the reserves data of the Company evaluated for the year ended December 2022, and identifies the respective portions thereof that we have evaluated and reported on to the Company's board of directors:
--- ---

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ ​ ​ ​ Location of Reserves ​ ​ ​ Net Present Value of Future Net Revenue
Independent Qualified Reserves ​ Effective Date of ​ (Country or Foreign ​ ​ ​ (before income taxes, 10% discount rate - M)
Evaluator **** Evaluation Report **** Geographic Area) **** Audited **** Evaluated Reviewed **** Total
GLJ Petroleum Consultants ​ ​ December 31, 2022 ​ Australia ​ — ​ 420,796 — ​ 420,796
GLJ Petroleum Consultants ​ ​ December 31, 2022 Canada — 5,015,475 — 5,015,475
GLJ Petroleum Consultants ​ ​ December 31, 2022 CEE — 183,177 — 183,177
GLJ Petroleum Consultants ​ ​ December 31, 2022 France — 1,166,273 — 1,166,273
GLJ Petroleum Consultants ​ ​ December 31, 2022 Germany — 1,666,977 — 1,666,977
GLJ Petroleum Consultants ​ ​ December 31, 2022 Ireland — 1,058,289 — 1,058,289
GLJ Petroleum Consultants ​ ​ December 31, 2022 Netherlands — 808,453 — 808,453
GLJ Petroleum Consultants ​ ​ December 31, 2022 United States — 980,585 — 980,585
Total ​ **** **** **** **** **** — **** 11,300,025 — **** 11,300,025

All values are in US Dollars.

​

6. In our opinion, the reserves data evaluated by us have, in all material respects, been determined and are in accordance with the COGE Handbook, consistently applied. We express no opinion on the reserves data that we reviewed but did not audit or evaluate.
7. We have no responsibility to update our reports referred to in paragraph 5 for events and circumstances occurring after the effective date of our reports.
--- ---
8. Because the reserves data are based on judgments regarding future events, actual results will vary and the variations may be material.
--- ---

​

EXECUTED as to our reports referred to above:

​

GLJ Petroleum Consultants Ltd., Calgary, Alberta, Canada, February 14, 2023

​

"Jodi L. Anhorn"
Jodi L. Anhorn, M.Sc., P.Eng.
Executive Vice President & COO

​

​

​ Vermilion Energy Inc. ■ Page 64 ■ 2022 Annual Information Form

Appendix B

​

REPORT OF MANAGEMENT AND DIRECTORS ON OIL AND GAS DISCLOSURE (FORM 51-101F3)

​

Terms to which a meaning is ascribed in National Instrument 51-101 have the same meaning herein.

​

Management of Vermilion Energy Inc. (the "Company") are responsible for the preparation and disclosure of information with respect to the Company's oil and gas activities in accordance with securities regulatory requirements. This information includes reserves data and related future net revenue as at December 31, 2022, estimated using forecast prices and costs.

​

An independent qualified reserves evaluator has evaluated the Company's reserves data. The report of the independent qualified reserves evaluator is presented in Appendix A to the Annual Information Form of the Company for the year ended December 31, 2022.

​

The Independent Reserves Committee of the Board of Directors of the Company has:

​

(a) reviewed the Company's procedures for providing information to the independent qualified reserves evaluator;
(b) met with the independent qualified reserves evaluator to determine whether any restrictions affected the ability of the independent qualified reserves evaluator to report without reservation; and
--- ---
(c) reviewed the reserves data with management and the independent qualified reserves evaluator.
--- ---

​

The Independent Reserves Committee of the Board of Directors has reviewed the Company's procedures for assembling and reporting other information associated with oil and gas activities and has reviewed that information with management. The Board of Directors has, on the recommendation of the Audit and Independent Reserves Committees, approved:

​

(a) the content and filing with securities regulatory authorities of Form 51-101F1 containing reserves data and other oil and gas information;
(b) the filing of Form 51-101F2 which is the report of the independent qualified reserves evaluator on the reserves data; and
--- ---
(c) the content and filing of this report.
--- ---

​

Because the reserves data is based on judgments regarding future events, actual results will vary and the variations may be material.

​

“Dion Hatcher”
Dion Hatcher, President and Chief Executive Officer
"Lars Glemser"
Lars Glemser, Vice President and Chief Financial Officer
“Robert Michaleski”
Robert Michaleski, Director and Chairman of the Board
“William Roby”
William Roby, Director
​
March 8, 2023

​

​

​ Vermilion Energy Inc. ■ Page 65 ■ 2022 Annual Information Form

Appendix C

​

Audit Committee Mandate

​

​

The primary function of the Audit Committee (the "Committee") is to assist the Board of Directors (the "Board") of Vermilion Energy Inc. (the "Corporation") in its oversight role with respect to matters including:

​

i. the Corporation’s accounting and financing reporting processes and the audit of the Corporation’s financial statements;
ii. the quality and integrity of financial information;
--- ---
iii. the Corporations’ compliance with legal and regulatory requirements;
--- ---
iv. the effectiveness of the Corporation’s systems of disclosure controls and internal controls regarding finance, accounting, legal, regulatory compliance and ethics;
--- ---
v. the effectiveness or risk management and compliance practices;
--- ---
vi. recommend the independent external auditors’ appointment (the “auditor”) performance, qualifications and independence;
--- ---
vii. related party transactions; and
--- ---
viii. he preparation of a report of the Committee to be included in the annual management proxy circular of the Corporation,
--- ---

​

with management of the Corporation responsible for the Corporation's financial reporting, information systems, risk management, disclosure controls, internal controls and compliance.

​

1. Committee Structure and Operations

​

1.1 The Committee shall consist of not less than three directors and not more than five directors.
1.2 Each member of the Committee shall satisfy the applicable independence^(1)^ and experience requirements of the laws governing the Corporation and the applicable rules of any stock exchange on which the Corporation’s securities are listed.
--- ---
1.3 All Committee members shall be "financially literate"^(2)^, and at least one member shall have "accounting or related financial expertise" as such terms are interpreted by the Board in its business judgment in light of, and in accordance with, the requirements or guidelines for audit committee service under applicable securities laws and rules of any stock exchange on which the Corporation’s securities are listed.
--- ---
1.4 No Committee member shall serve on the audit committees of more than two other public issuers without prior determination by the Board that such simultaneous service would not impair the member's independence or the ability of such member to serve effectively on the Committee.
--- ---
1.5 The Committee shall meet at least four times each year.
--- ---
1.6 The Committee shall meet in-camera without management present with: (i) the external auditor, (ii) the internal auditor; and (iii) the members of the Committee.
--- ---

​

2. Financial Information and Reporting

​

2.1 The Committee will review and recommend for approval to the Board financial information that will be made publicly available. This includes the responsibility to:

​

i. Review and recommend approval of the Corporation's annual financial statements and related MD&A and earnings press releases.
ii. Review and recommend approval of the Corporation's quarterly financial statements and related MD&A and earnings press releases.
--- ---
iii. Ensure adequate procedures are in place for the review of the public disclosure of financial information extracted or derived from the Corporation's filed financial reporting, other than the public disclosure referred to in items (i) and (ii) above, and periodically assess the adequacy of those procedures.
--- ---
iv. Review and recommend approval by the Board of the Corporation's Annual Information Form and any financing disclosure documents (as required).
--- ---

​

1 Committee members must be “independent”, as defined in Sections 1.4 and 1.5 of National Instrument 52-110 and ‘‘independent’’ under the requirements of Rule 10A-3 of the Securities Exchange Act of 1934, as amended, and Section 303A.06 of the NYSE Listed Company Manual.
2 The Board has adopted the NI 52-110 definition of "financial literacy", which is an individual is financially literate if he or she has the ability to read and understand a set of financial statements that present a breadth and level of complexity of accounting issues that are generally comparable to the breadth and complexity of the issues that can reasonably be expected to be raised by the issuer's financial statements.
--- ---

​ Vermilion Energy Inc. ■ Page 66 ■ 2022 Annual Information Form

2.2 Review and consider:

​

i. The critical accounting policies and financial reporting practices used by the Corporation (including the appropriateness thereof).
ii. Issues regarding accounting principles and financial statement presentations, including any significant proposed changes in financial reporting and accounting principles, policies and practices to be adopted by the Corporation.
--- ---
iii. Financial reporting issues and judgments made in connection with the preparation of the financial statements, including analyses of the effects of alternative International Financial Reporting Standards (the “IFRS”) methods on the financial statements of the Corporation and any other opinions sought by management from an independent or other audit firm or advisor with respect to the accounting treatment of a particular item.
--- ---
iv. Any management letter or schedule of unadjusted differences provided by the auditor and the Corporation’s response to that letter and other material written communication between auditor and management.
--- ---
v. Any problems, difficulties or differences encountered in the course of the audit work including any disagreements with management or restrictions on the scope of the auditor’s activities or on access to requested information and management’s response thereto.
--- ---
vi. Any new or pending developments in accounting and reporting standards that may affect the Corporation.
--- ---
vii. The effect of regulatory and accounting initiatives, as well as any off-balance sheet structures on the financial statements of the Corporation and other financial disclosures.
--- ---
viii. Any reserves, accruals, provisions or estimates that may have a material effect upon the financial statements of the Corporation.
--- ---
ix. The use of special purpose entities and the business purpose and economic effect of off-balance sheet transactions, arrangements, obligations, guarantees and other relationships of Corporation and their impact on the reported financial results of the Corporation.
--- ---
x. The use of any “pro forma” or “adjusted” information not in accordance with generally accepted accounting principles.
--- ---
xi. Any litigation, claim or contingency, including tax assessments, that could have a material effect upon the financial position of the Corporation, and the manner in which these matters may be, or have been, disclosed in the financial statements; and
--- ---
xii. Any other accounting, tax and financial aspects of the operations of the Corporation as the Committee considers appropriate.
--- ---

​

**3.**Oversight of Independent External Auditor

​

3.1 Recommend to the Board for approval the auditor to be appointed auditor of the Corporation or successor auditor of the Corporation in the event of the termination, resignation or removal of the auditor.
3.2 Recommend to the Board the remuneration of the auditor.
--- ---
3.3 Review and approve the scope and terms of all audit engagements.
--- ---
3.4 Satisfy itself that the audit plan proposed by the auditor is risk-based and addresses all the relevant activities.
--- ---
3.5 Pre-approve all audit services and permitted non-audit services (including fees terms and conditions for the performance of such services) to be provided by the auditor.
--- ---
3.6 Oversee the performance by the auditor of its engagement and report to the Board on relevant matters, including but not limited to:
--- ---
i. The Corporation’s quarterly and annual financial statements and the auditor’s reporting in respect thereof including the appropriateness of policies and underlying estimates.
--- ---
ii. Any significant accounting or financial reporting issues.
--- ---
iii. Any material issues or potentially material issues, either specific to the Corporation or to the financial reporting environment in general, identified by the auditor.
--- ---
iv. The resolution of any disagreements between management and the auditor regarding financial reporting.
--- ---
3.7 Evaluate the qualifications, performance and independence of the auditor, including:
--- ---
i. Review and evaluate the proposed lead audit partner.
--- ---
ii. Ensure the rotation of the lead audit partner occurs in accordance with applicable requirements.
--- ---
iii. Receive on periodic basis a written statement from the auditors confirming its independence, including a list of relationships between the auditor and the Corporation that may reasonably be expected to impact the independence of the auditor.
--- ---
iv. Discuss with the auditor any relationships or services that the auditor reasonably believes may affect the objectivity and independence of the auditors, and recommend to the Board appropriate action in response thereto.
--- ---
v. Annually request and review a report from the auditor regarding:
--- ---
a) the auditor’s quality-control procedures;
--- ---
b) any material issues raised by the most recent quality-control review, or peer review, of the auditor, or by any inquiry or investigation by governmental or professional authorities within the preceding five years respecting one or more independent audits carried out by the firm; and
--- ---
c) any steps taken in respect of any such issues.
--- ---
3.8 Ensure the auditor receives, during its term of office, notice of every meeting of the Committee and, if so requested by the Chair of the Committee, attends such meetings.
--- ---
3.9 Meet with auditor in camera without management present.
--- ---

​ Vermilion Energy Inc. ■ Page 67 ■ 2022 Annual Information Form

**4.**Risk Management Oversight

​

4.1 The Committee is responsible for the oversight of management’s identification, and evaluation, of the Corporation’s principal risks, and the implementation of appropriate policies, processes and systems to manage or mitigate the risks within the Corporation’s risk framework.
4.2 The Committee shall:
--- ---

​

i. Oversee, and ensure management reports annually to Board in respect of:
a) the Corporation's principal risks and overall risk profile;
--- ---
b) the Corporation's strategies in addressing its risk profile;
--- ---
c) the processes, policies, procedures and controls in place to manage or mitigate the Corporation's principal risks; and
--- ---
d) the overall effectiveness of the enterprise risk management process and program.
--- ---
ii. Oversee the Corporation's credit and counterparty, market and financial, political and strategic, and repatriation risks.
--- ---
iii. Receive and review managements' annual risk register update including an update on residual risks.
--- ---
iv. Review the Corporation's annual insurance program, including the risk retention philosophy, potential exposure and corporate liability protection programs and ensure management reports to the Board in respect thereof.
--- ---

​

**5.**Internal Controls

​

5.1 Oversee, and review and approve as required:
i. Processes adopted by management for establishing effective internal control over financial reporting (the "ICFR") and disclosure controls and procedures (the "DC&P").
--- ---
ii. The adequacy and effectiveness of the Corporation’s accounting, ICFR and DC&P policies and procedures and management information systems.
--- ---
iii. Changes to the Corporation's ICFR, DC&P and management information systems.
--- ---
iv. Oversee management's certification of ICFR and DC&P.
--- ---
v. Spending authority and approval limits.
--- ---

​

**6.**Information Technology – Cyber Security

​

6.1 Receive annually (or more frequently as the Committee may request) a system status update with respect to the Corporation's core IT operating systems.
6.2 Review annually (or more frequently as the Committee may request) the Corporation's cyber security programs and their effectiveness.
--- ---
6.3 Receive as frequently as the Committee may request an update on the Corporation's compliance program for cyber threats and security.
--- ---
6.4 Ensure significant breaches are reported in accordance with best governance practices.
--- ---

​

7. Environment, Social and Governance (“ESG”)

​

7.1 In collaboration with the Sustainability Committee, review and assess ESG-related risks to the Corporation
7.2 Regularly review the Corporations’ risk management policies and processes for, and approach to, addressing ESG-related risks.
--- ---
7.3 Review ESG disclosure.
--- ---

​

**8.**General Compliance

​

8.1Oversee, and periodically review, procedures for:

i. The confidential, anonymous submission by employees of concerns regarding questionable accounting or auditing matters or other matters that could negatively affect the Corporation, such as violations of the Code of Business Conduct and Ethics.
ii. Treatment of complaints regarding accounting, internal accounting controls, or auditing matters.
--- ---
iii. The review and approval of the President and Chairman’s expenses and perquisites.
--- ---
iv. The review of any transactions involving the Corporation in which directors or officers of the Corporation have a material interest.
--- ---

​ Vermilion Energy Inc. ■ Page 68 ■ 2022 Annual Information Form

​

Duties and Responsibilities Meeting
​ Q1 Q2 Q3 Q4
2. Financial Information and Reporting ​ ​ ​ ​
2.1 Responsibilities include: ​ ​ ​ ​
i. Review and recommend approval of the Corporation's annual financial statements, and related MD&A and earnings press releases. ✓ ​ ​ ​
ii. Review and recommend Board approval of quarterly financial statements, MD&A and press release. ​ ✓ ✓ ✓
iii. Ensure adequate procedures are in place for the review of the public disclosure of financial information extracted or derived from the Corporation's filed financial reporting, other than the public disclosure referred to in items (i) and (ii) above, and periodically assess the adequacy of those procedures. ✓ ✓ ✓ ✓
iv. Review Annual Information Form ✓ ​ ​ ​
2.2 Review and consider: ​ ​ ​ ​
i. The critical accounting policies and financial reporting practices used by the Corporation, including the appropriateness thereof. As needed.
iIi. Issues regarding accounting principles and financial statement presentations, including any significant proposed changes in financial reporting and accounting principles, policies and practices to be adopted by the Corporation. As needed.
iii. Financial reporting issues and judgments made in connection with the preparation of the financial statements, including analyses of the effects of alternative IFRS methods on the financial statements of the Corporation and any other opinions sought by management from an independent or other audit firm or advisor with respect to the accounting treatment of a particular item. As needed.
iv. Any management letter or schedule of unadjusted differences provided by the external auditor and the Corporation’s response to that letter and other material written communication between the external auditor and management. As needed.
v. Any problems, difficulties or differences encountered in the course of the audit work including any disagreements with management or restrictions on the scope of the external auditor’s activities or on access to requested information and management’s response thereto. As needed.
vi. Any new or pending developments in accounting and reporting standards that may affect the Corporation. As needed.
vii. The effect of regulatory and accounting initiatives, as well as any off-balance sheet structures on the financial statements of the Corporation and other financial disclosures. As needed.
viii. Any reserves, accruals, provisions or estimates that may have a material effect upon the financial statements of the Corporation. As needed.
ix. The use of special purpose entities and the business purpose and economic effect of off balance sheet transactions, arrangements, obligations, guarantees and other relationships of Corporation and their impact on the reported financial results of the Corporation. As needed.
x. The use of any “pro forma” or “adjusted” information not in accordance with generally accepted accounting principles. As needed.
xi. Any litigation, claim or contingency, including tax assessments, that could have a material effect upon the financial position of the Corporation, and the manner in which these matters may be, or have been, disclosed in the financial statements. As needed.
xii. Any other accounting, tax and financial aspects of the operations of the Corporation as the Committee considers appropriate. As needed.
​ ​
3. Independent External Auditor ​ ​ ​ ​
3.1 Recommend to the Board for approval the independent auditor to be appointed as auditor of the Corporation or successor auditor of the Corporation in the event of the termination, resignation or removal of the auditor. ✓ ​ ​ ​
3.2 Recommend to the Board the remuneration of the independent auditor. ✓ ​ ​ ​
3.3 Review and approve the scope and terms of all audit engagements. ✓ ​ ​ ​
3.4 Satisfy itself that the audit plan proposed by the auditor is risk-based and addresses all the relevant activities. As needed.
3.5 Pre-approve all audit services and permitted non-audit services (including fees terms and conditions for the performance of such services) to be provided by the independent auditor. As needed.
3.6 Oversee the performance of independent external auditor and report to the Board on the relevant items. ✓ ✓ ✓ ✓
i. The Corporation’s quarterly and annual financial statements and the auditor’s reporting in respect thereof including the appropriateness of policies and underlying estimates. ✓ ✓ ✓ ✓
ii. Any significant accounting or financial reporting issues. ✓ ✓ ✓ ✓
iii. Any material issues or potentially material issues, either specific to the Corporation or to the financial reporting environment in general identified by the auditor. ✓ ✓ ✓ ✓
iv. The resolution of any disagreements between management and external auditor regarding financial reporting. ✓ ✓ ✓ ✓
3.7 Evaluate the qualifications, performance and independence of the auditor ​ ​ ​ ​
i.Review and evaluate the proposed lead audit partner. ✓ ✓ ✓ ✓
ii. Ensure the rotation of the lead audit partner occurs in accordance with applicable requirements. ✓ ✓ ✓ ✓
iii. Receive on periodic basis a written statement from the external auditors confirming its independence, including a list of relationships between the external auditor and the Corporation that may reasonably be expected to impact the independence of the external auditor. ✓ ✓ ✓ ✓
iv. Discuss with the external auditor any relationships or services that the external auditor reasonably believes may affect the objectivity and independence of the external auditors, and recommend to the Board appropriate action in response thereto. ✓ ✓ ✓ ✓
v. Annually request and review a report from the external auditor regarding:<br><br>-Auditor’s quality control procedures.<br><br>-Any material issues raised by the most recent quality-control review.<br><br>-Steps taken in respect of any such issues. ✓ ​ ​ ​
3.8 Ensure the external independent auditor receives, during its term of office, notice of every meeting of the Committee and, if so requested by the Chair of the Committee, attends such meetings. ​ ​ ​ ✓
3.9 Meet with auditor in camera without management present. ✓ ✓ ✓ ✓
​ ​

​

​ Vermilion Energy Inc. ■ Page 69 ■ 2022 Annual Information Form

​

4. Risk Management ​ ​ ​ ​
4.2 The Committee shall: ✓ ✓ ✓ ✓
i.Oversee, and ensure management reports and reviews annually to the Board in respect of:<br><br>- the Corporation's principal risks and overall risk profile;<br><br>- the Corporation's strategies in addressing its risk profile;<br><br>- the processes, policies, procedures and controls in place to manage or mitigate the Corporation’s principal risks; and<br><br>- the overall effectiveness of the enterprise risk management process and program. ​ ​ ​ ​
ii. Oversee the Corporation's credit and counterparty, market and financial, political and strategic, and repatriation risks. ✓ ✓ ✓ ✓
iii. Receive and review managements' annual risk register update including an update on residual risks. ​ ​ ✓ ​
iv. Review the Corporation's annual insurance program, including the risk retention philosophy, potential exposure and corporate liability protection programs and ensure management reports to the Board in respect thereof. ​ ​ ​ ​
​ ​
5. Internal Controls ​ ​ ​ ​
5.1 The Committee shall review and approve as required: ​ ​ ​ ​
i.Processes adopted by management for establishing effective internal control over financial reporting ICFR and DC&P. ✓ ✓ ✓ ✓
ii. The adequacy and effectiveness of the Corporation’s accounting, ICFR and DC&P policies and procedures and management information systems. ✓ ✓ ✓ ✓
iii. Changes to the Corporation's ICFR, DC&P and management information systems. ✓ ✓ ✓ ✓
iv. Oversee management's certification of ICFR and DC&P. ✓ ✓ ✓ ✓
v. Spending authority and approval of limits. ✓ ✓ ✓ ✓
​ ​
6. Information Technology – Cyber Security ​ ​ ​ ​
6.1 Receive annually (or more frequently as the Committee may request) a system status update with respect to the Corporation's core IT operating systems. ​ ​ ​ ✓
6.2 Review annually (or more frequently as the Committee may request) the Corporation's cyber security programs and their effectiveness. ​ ​ ​ ✓
6.3 Receive as frequently as the Committee may request an update on the Corporation's compliance program for cyber threats and security. As needed.
6.4 Ensure significant breaches are reported in accordance with best governance practices. As needed.
​ ​
7. Environment, Social and Governance (“ESG”) ​ ​ ​ ​
7.1 In collaboration with the Sustainability Committee, review and assess ESG-related risks to the Corporation. ✓ ✓ ✓ ✓
7.2 Regularly review the Corporations’ risk management policies and processes for, and approach to, addressing ESG-related risks. ✓ ✓ ✓ ✓
7.3 Review ESG disclosure. ✓ ✓ ✓ ✓
​ ​
8. General Compliance ​ ​ ​ ​
8.1 Oversee, and periodically review procedures for: As needed.
i.The confidential, anonymous submission by employees of concerns regarding questionable accounting or auditing matters or other matters that could negatively affect the Corporation, such as violations of the Code of Business Conduct and Ethics.
ii.Treatment of complaints regarding accounting, internal accounting controls, or auditing matters.
iii.The review and approval of the President and Chairman’s expenses and perquisites.
iv.The review of any transactions involving the Corporation in which directors or officers of the Corporation have a material interest.
8.2 Review this mandate and make recommendations to the Board as appropriate. ​ ​ ​ ✓

​ Vermilion Energy Inc. ■ Page 70 ■ 2022 Annual Information Form

Exhibit 99.2

​

Disclaimer

​

Certain statements included or incorporated by reference in this document may constitute forward-looking statements or information under applicable securities legislation. Such forward-looking statements or information typically contain statements with words such as "anticipate", "believe", "expect", "plan", "intend", "estimate", "propose", or similar words suggesting future outcomes or statements regarding an outlook. Forward looking statements or information in this document may include, but are not limited to: capital expenditures and Vermilion’s ability to fund such expenditures; Vermilion’s additional debt capacity providing it with additional working capital; statements regarding the return of capital, the flexibility of Vermilion’s capital program and operations; business strategies and objectives; operational and financial performance; estimated volumes of reserves and resources; petroleum and natural gas sales; future production levels and the timing thereof, including Vermilion’s 2023 guidance, and rates of average annual production growth; the effect of changes in crude oil and natural gas prices, changes in exchange and inflation rates; significant declines in production or sales volumes due to unforeseen circumstances; the effect of possible changes in critical accounting estimates; statements regarding the growth and size of Vermilion’s future project inventory wells expected to be drilled in 2023; exploration and development plans and the timing thereof; Vermilion’s ability to reduce its debt; statements regarding Vermilion’s hedging program, its plans to add to its hedging positions, and the anticipated impact of Vermilion’s hedging program on project economics and free cash flows; the potential financial impact of climate-related risks; acquisition and disposition plans and the timing thereof; operating and other expenses, including the payment and amount of future dividends; royalty and income tax rates and Vermilion’s expectations regarding future taxes and taxability; and the timing of regulatory proceedings and approvals.

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Such forward-looking statements or information are based on a number of assumptions, all or any of which may prove to be incorrect. In addition to any other assumptions identified in this document, assumptions have been made regarding, among other things: the ability of Vermilion to obtain equipment, services and supplies in a timely manner to carry out its activities in Canada and internationally; the ability of Vermilion to market crude oil, natural gas liquids, and natural gas successfully to current and new customers; the timing and costs of pipeline and storage facility construction and expansion and the ability to secure adequate product transportation; the timely receipt of required regulatory approvals; the ability of Vermilion to obtain financing on acceptable terms; foreign currency exchange rates and interest rates; future crude oil, natural gas liquids, and natural gas prices; and management’s expectations relating to the timing and results of exploration and development activities.

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Although Vermilion believes that the expectations reflected in such forward-looking statements or information are reasonable, undue reliance should not be placed on forward-looking statements because Vermilion can give no assurance that such expectations will prove to be correct. Financial outlooks are provided for the purpose of understanding Vermilion’s financial position and business objectives, and the information may not be appropriate for other purposes. Forward-looking statements or information are based on current expectations, estimates, and projections that involve a number of risks and uncertainties which could cause actual results to differ materially from those anticipated by Vermilion and described in the forward-looking statements or information. These risks and uncertainties include, but are not limited to: the ability of management to execute its business plan; the risks of the oil and gas industry, both domestically and internationally, such as operational risks in exploring for, developing and producing crude oil, natural gas liquids, and natural gas; risks and uncertainties involving geology of crude oil, natural gas liquids, and natural gas deposits; risks inherent in Vermilion's marketing operations, including credit risk; the uncertainty of reserves estimates and reserves life and estimates of resources and associated expenditures; the uncertainty of estimates and projections relating to production and associated expenditures; potential delays or changes in plans with respect to exploration or development projects; Vermilion's ability to enter into or renew leases on acceptable terms; fluctuations in crude oil, natural gas liquids, and natural gas prices, foreign currency exchange rates, interest rates, and inflation rates; health, safety, and environmental risks; uncertainties as to the availability and cost of financing; the ability of Vermilion to add production and reserves through exploration and development activities; the possibility that government policies or laws may change or governmental approvals may be delayed or withheld; uncertainty in amounts and timing of royalty payments; risks associated with existing and potential future law suits and regulatory actions against or involving Vermilion; and other risks and uncertainties described elsewhere in this document or in Vermilion's other filings with Canadian securities regulatory authorities.

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The forward-looking statements or information contained in this document are made as of the date hereof and Vermilion undertakes no obligation to update publicly or revise any forward-looking statements or information, whether as a result of new information, future events, or otherwise, unless required by applicable securities laws.

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This document contains references to sustainability/ESG data and performance that reflect metrics and concepts that are commonly used in such frameworks as the Global Reporting Initiative, the Task Force on Climate-related Financial Disclosures, and the Sustainability Accounting Standards Board. Vermilion has used best efforts to align with the most commonly accepted methodologies for ESG reporting, including with respect to climate data and information on potential future risks and opportunities, in order to provide a fuller context for our current and future operations. However, these methodologies are not yet standardized, are frequently based on calculation factors that change over time, and continue to evolve rapidly. Readers are particularly cautioned to evaluate the underlying definitions and measures used by other companies, as these may not be comparable to Vermilion's. While Vermilion will continue to monitor and adapt its reporting accordingly, the Company is not under any duty to update or revise the related sustainability/ESG data or statements except as required by applicable securities laws.

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All crude oil and natural gas reserve and resource information contained in this document has been prepared and presented in accordance with National Instrument 51-101 Standards of Disclosure for Oil and Gas Activities and the Canadian Oil and Gas Evaluation Handbook. Reserves

Vermilion Energy Inc.  ■  Page 1  ■  2022 Management's Discussion and Analysis

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estimates have been made assuming that development of each property in respect of which the estimate is made will occur, without regard to the likely availability of funding required for such development. The actual crude oil and natural gas reserves and future production will be greater than or less than the estimates provided in this document.

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Natural gas volumes have been converted on the basis of six thousand cubic feet of natural gas to one barrel of oil equivalent. Barrels of oil equivalent (boe) may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet to one barrel of oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead.

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Financial data contained within this document are reported in Canadian dollars unless otherwise stated.

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Vermilion Energy Inc.  ■  Page 2  ■  2022 Management's Discussion and Analysis

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Abbreviations

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$M thousand dollars
$MM million dollars
AECO the daily average benchmark price for natural gas at the AECO ‘C’ hub in Alberta
bbl(s) barrel(s)
bbls/d barrels per day
boe barrel of oil equivalent, including: crude oil, condensate, natural gas liquids, and natural gas (converted on the basis of one boe for six mcf of natural gas)
boe/d barrel of oil equivalent per day
GJ gigajoules
LSB light sour blend crude oil reference price
mbbls thousand barrels
mcf thousand cubic feet
mmcf/d million cubic feet per day
NBP the reference price paid for natural gas in the United Kingdom at the National Balancing Point Virtual Trading Point
NGLs natural gas liquids, which includes butane, propane, and ethane
PRRT Petroleum Resource Rent Tax, a profit based tax levied on petroleum projects in Australia
tCO2e tonnes of carbon dioxide equivalent
TTF the price for natural gas in the Netherlands, quoted in megawatt hours of natural gas, at the Title Transfer Facility Virtual Trading Point
WTI West Texas Intermediate, the reference price paid for crude oil of standard grade in US dollars at Cushing, Oklahoma

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Vermilion Energy Inc.  ■  Page 3  ■  2022 Management's Discussion and Analysis

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Management's Discussion and Analysis

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The following is Management’s Discussion and Analysis (“MD&A”), dated March 8, 2023, of Vermilion Energy Inc.’s (“Vermilion”, “we”, “our”, “us” or the “Company”) operating and financial results as at and for the three months and year ended December 31, 2022 compared with the corresponding periods in the prior year.

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This discussion should be read in conjunction with the audited consolidated financial statements for the year ended December 31, 2022 and 2021, together with the accompanying notes. Additional information relating to Vermilion, including its Annual Information Form, is available on SEDAR at www.sedar.com or on Vermilion’s website at www.vermilionenergy.com.

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The audited consolidated financial statements for the year ended December 31, 2022 and comparative information have been prepared in Canadian dollars and in accordance with International Financial Reporting Standards (“IFRS” or, alternatively, “GAAP”) as issued by the International Accounting Standards Board ("IASB").

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This MD&A includes references to certain financial and performance measures which do not have standardized meanings prescribed by IFRS. These measures include:

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● Fund flows from operations: Fund flows from operations (FFO) is a total of segments measure most directly comparable to net earnings and is comprised of sales excluding royalties, transportation, operating, G&A, corporate income tax, PRRT, windfall taxes, interest expense, realized loss on derivatives, realized foreign exchange gain (loss), and realized other income. The measure is used to assess the contribution of each business unit to Vermilion's ability to generate income necessary to pay dividends, repay debt, fund asset retirement obligations and make capital investments. A reconciliation to Net Earnings can be found within the "Non-GAAP and Other Specified Financial Measures" section of this MD&A.
● Free cash flow: Free cash flow (FCF) is a non-GAAP financial measure most directly comparable to Cash flows used in investing activities and is comprised of FFO less drilling and development costs and exploration and evaluation costs. The measure is used to determine the funding available for investing and financing activities including payment of dividends, repayment of long-term debt, reallocation into existing business units and deployment into new ventures. A reconciliation to Cash flows used in investing activities can be found within the "Non-GAAP and Other Specified Financial Measures" section of this MD&A.
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● Net debt: Net debt is a capital management measure in accordance with IAS 1 "Presentation of Financial Statements" and is most directly comparable to long-term debt. Net debt is comprised of long-term debt (excluding unrealized foreign exchange on swapped USD borrowings) plus adjusted working capital (defined as current assets less current liabilities, excluding current derivatives and current lease liabilities), and represents Vermilion's net financing obligations after adjusting for the timing of working capital fluctuations. Net debt excludes lease obligations which are secured by a corresponding right-of-use asset. A reconciliation to long term-debt can be found within the "Financial Position Review" section of this MD&A.
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● Operating Netbacks: Operating Netbacks is a non-GAAP financial measure most directly comparable to net earnings and is calculated as sales less royalties, operating expense, transportation costs, PRRT, and realized hedging gains and losses presented on a per unit basis. Management assesses operating netback as a measure of the profitability and efficiency of our field operations. A reconciliation to the primary financial statement measures can be found within "Supplemental Table 1: Netbacks" of this MD&A.
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● Fund flows from operations per boe: Fund flows from operations per boe includes general and administration expense. Fund flows from operations netback is used by management to assess the profitability of our business units and Vermilion as a whole. A reconciliation to the primary financial statement measures can be found within "Supplemental Table 1: Netbacks" of this MD&A.
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In addition, this MD&A includes references to certain financial measures which are not specified, defined, or determined under IFRS and are therefore considered non-GAAP and other specified financial measures. These financial measures are unlikely to be comparable to similar financial measures presented by other issuers. For a full description of these non-GAAP and other specified financial measures and a reconciliation of these measures to their most directly comparable GAAP measures, please refer to “Non-GAAP and Other Specified Financial Measures”.

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Product Type Disclosure

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Under National Instrument 51-101 "Standards of Disclosure for Oil and Gas Activities", disclosure of production volumes should include segmentation by product type as defined in the instrument. In this report, references to "crude oil" and "light and medium crude oil" mean "light crude oil and medium crude oil" and references to "natural gas" mean "conventional natural gas".

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In addition, in Supplemental Table 4 "Production", Vermilion provides a reconciliation from total production volumes to product type and also a reconciliation of "crude oil and condensate" and "NGLs" to the product types "light crude oil and medium crude oil" and "natural gas liquids".

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Vermilion Energy Inc.  ■  Page 4  ■  2022 Management's Discussion and Analysis

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Production volumes reported are based on quantities as measured at the first point of sale.

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Guidance

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On November 29, 2021, we released our 2022 capital budget and associated production guidance. On March 28, 2022, we increased our 2022 capital expenditure guidance to $500 million and our 2022 annual production guidance to 86,000 to 88,000 boe/d to reflect the post-closing impact of the acquisition of Leucrotta Exploration Inc. On August 11, 2022, as a result of forest fire related downtime in France and offshore drilling delays in Australia, combined with inflationary pressure, we increased our 2022 budget by $50 million to $550 million.

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The following table summarizes our 2022 guidance:

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​ ​ ​ ​ ​ ​
​ **** Date **** Capital Expenditures (MM) Production (boe/d)
2022 Guidance ​ ​ ​ ​ ​
2022 Guidance ​ November 29, 2021 425 83,000 - 85,000
2022 Guidance ​ March 28, 2022 500 86,000 - 88,000
2022 Guidance ​ August 11, 2022 550 86,000 - 88,000
2022 Actual Results ​ March 8, 2023 552 85,187

All values are in US Dollars.

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On January 6, 2023, we released our 2023 capital budget and associated production guidance. Our 2023 guidance assumes the Corrib acquisition will close on March 31, 2023. On March 8, 2023, we decreased annual production guidance to 82,000 to 86,000 boe/d to reflect the southeast Saskatchewan asset sale and unplanned downtime in Australia, and decreased operating expense guidance to reflect the southeast Saskatchewan asset sale and lower European gas prices. Revisions to other guidance items reflect the assumptions used in management's most recent forecast. The Company's guidance for 2023 is as follows:

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​ ​ ​ ​ ​ ​ ​
Category Prior ^(1)^ **** Revised ^(1)^ ****
Production (boe/d) ​ 87,000 - 91,000 ​ 82,000 - 86,000 ​
E&D Capital Expenditures (MM) ​ 570 ​ 570 ​
Royalty rate (%) (2) ​ 8 - 10 % ​ 9 - 11 %
Operating (/boe) $ 17.50 - 18.50 ​ $ 16.50 - 17.50 ​
Transportation (/boe) $ 2.75 - 3.25 ​ $ 3.00 - 3.50 ​
General and administration (/boe) $ 2.00 - 2.50 ​ $ 2.00 - 2.50 ​
Cash taxes (% of pre-tax FFO) 11 - 13 % 7 - 9 %
Windfall tax (% of pre-tax FFO) (3) 14 - 16 % 12 - 14 %

All values are in US Dollars.

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(1) Revised 2023 guidance reflects foreign exchange assumptions of CAD/USD 1.35, CAD/EUR 1.45, and CAD/AUD 0.92. Prior 2023 guidance reflected foreign exchange assumptions of CAD/USD 1.36, CAD/EUR 1.46, and CAD/AUD 0.92.

(2)Royalty rate guidance excludes windfall royalties paid as part of the European Solidarity Contribution.

(3) Windfall tax guidance is based on forward prices as at February 27, 2023 (prior as at December 30, 2022), and incorporates all forms of solidarity payments including windfall taxes and windfall royalties net of tax.

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Vermilion's Business

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Vermilion is a Calgary, Alberta-based international oil and gas producer focused on the acquisition, exploration, development, and optimization of producing properties in North America, Europe, and Australia. We manage our business through our Calgary head office and our international business unit offices.

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Vermilion Energy Inc.  ■  Page 6  ■  2022 Management's Discussion and Analysis

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Consolidated Results Overview

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​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ ​ ​ ​ Q4/22 vs. ​ ​ ​ ​ ​ 2022 vs. ​
​ Q4 2022 **** Q4 2021 **** Q4/21 **** 2022 **** 2021 **** 2021 ****
Production (1) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Crude oil and condensate (bbls/d) 38,915 36,264 ​ 7 % 37,530 38,143 (2) %
NGLs (bbls/d) 7,497 8,461 ​ (11) % 7,961 8,325 (4) %
Natural gas (mmcf/d) 234.23 238.16 ​ (2) % 238.18 233.64 2 %
Total (boe/d) 85,450 84,417 ​ 1 % 85,187 85,408 — %
(Draw) build in inventory (mbbls) (242) (144) ​ ​ 39 44 ​
Financial metrics ​ ​ ​
Fund flows from operations (M) (2) 284,220 322,173 ​ (12) % 1,634,865 919,862 78 %
Per share (/basic share) 1.74 1.99 ​ (13) % 10.00 5.71 75 %
Net earnings (M) 395,408 344,588 ​ 15 % 1,313,062 1,148,696 14 %
Per share (/basic share) 2.42 2.12 ​ 14 % 8.03 7.13 13 %
Cash flows from operating activities (M) 495,195 ​ 250,352 ​ 98 % 1,814,220 ​ 834,453 ​ 117 %
Free cash flow (M) (3) 114,915 ​ 176,366 ​ (35) % 1,083,048 ​ 545,066 ​ 99 %
Long-term debt (M) 1,081,351 1,651,569 ​ (35) % 1,081,351 1,651,569 (35) %
Net debt (M) (4) 1,344,586 1,644,786 ​ (18) % 1,344,586 1,644,786 (18) %
Activity ​ ​ ​
Capital expenditures (M)(5) 169,305 145,807 ​ 16 % 551,817 374,796 47 %
Acquisitions (M)(6) 4,558 23,633 ​ ​ 539,713 130,965 ​

All values are in US Dollars.

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^(1)^ Please refer to Supplemental Table 4 "Production" for disclosure by product type.
^(2)^ Fund flows from operations (FFO) and FFO per share are a total of segments measure and supplementary financial measure respectively most directly comparable to net earnings and net earnings per share, respectively. The measures do not have a standardized meaning under IFRS and therefore may not be comparable to similar measures presented by other issuers. FFO is comprised of sales excluding royalties, transportation, operating, G&A, corporate income tax, PRRT, windfall taxes, interest expense, and realized loss (gain) on derivatives, plus realized gain (loss) on foreign exchange and realized other income. The measure is used to assess the contribution of each business unit to Vermilion's ability to generate income necessary to pay dividends, repay debt, fund asset retirement obligations and make capital investments. A reconciliation to the primary financial statement measures can be found within the "Non-GAAP and Other Specified Financial Measures" section of this MD&A.
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^(3)^ Free cash flow (FCF) is a non-GAAP financial measure most directly comparable to cash flows from operating activities; it does not have a standardized meaning under IFRS and therefore may not be comparable to similar measures presented by other issuers. FCF is comprised of fund flows from operations less drilling and development costs and exploration and evaluation costs. The measure is used to determine the funding available for investing and financing activities including payment of dividends, repayment of long-term debt, reallocation into existing business units and deployment into new ventures. A reconciliation to primary financial statement measures can be found within the "Non-GAAP and Other Specified Financial Measures" section of this MD&A.
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^(4)^ Net debt is a capital management measure in accordance with IAS 1 "Presentation of Financial Statements" and is most directly comparable to long-term debt. Net debt is comprised of long-term debt (excluding unrealized foreign exchange on swapped USD borrowings) plus adjusted working capital (defined as current assets less current liabilities, excluding current derivatives and current lease liabilities), and represents Vermilion's net financing obligations after adjusting for the timing of working capital fluctuations. Net debt excludes lease obligations which are secured by a corresponding right-of-use asset. A reconciliation to the primary financial statement measures can be found within the "Financial Position Review" section of this MD&A.
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^(5)^ Capital expenditures is a non-GAAP financial measure that does not have a standardized meaning under IFRS and therefore may not be comparable to similar measures presented by other issuers. The measure is calculated as the sum of drilling and development costs and exploration and evaluation costs from the Consolidated Statements of Cash Flows. We consider capital expenditures to be a useful measure of our investment in our existing asset base. Capital expenditures are also referred to as E&D capital. A reconciliation to the primary financial statement measures can be found within the "Non-GAAP and Other Specified Financial Measures" section of this MD&A.
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^(6)^ Acquisitions is a non-GAAP financial measure that does not have a standardized meaning under IFRS and therefore may not be comparable to similar measures presented by other issuers. The measure is calculated as the sum of acquisitions from the Consolidated Statements of Cash Flows, Vermilion common shares issued as consideration, the estimated value of contingent consideration, the amount of acquiree's outstanding long-term debt assumed plus or net of acquired working capital deficit or surplus. We believe that including these components provides a useful measure of the economic investment associated with our acquisition activity. A reconciliation to the acquisitions line item in the Consolidated Statements of Cash Flows can be found in "Supplemental Table 3: Capital Expenditures and Acquisitions" section of this MD&A.
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Financial performance review

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Q4 2022 vs. Q4 2021

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Graphic

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·We recorded net earnings of $395.4 million ($2.42/basic share) for Q4 2022 compared to $344.6 million ($2.12/basic share) in Q4 2021. The increase in net earnings was primarily due to a change in the position of unrealized derivative loss in Q4 2022 by $377.4 million driven by changes in our mark-to-market position and settlements. This was partially offset by deferred taxes resulting from increased taxable income and lower fund flows from operations as the full year impact of 2022 windfall taxes ($222.9 million) was accrued in Q4, 2022.

Graphic

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Vermilion Energy Inc.  ■  Page 8  ■  2022 Management's Discussion and Analysis

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● We generated cash flows from operating activities of $495.2 million in Q4 2022 compared to $250.4 million in Q4 2021 and fund flows from operations of $284.2 million in Q4 2022 compared to $322.2 million in Q4 2021. The decrease in fund flows from operations was primarily due to the recognition of the full year impact of 2022 windfall taxes ($222.9 million) in Q4 2022. These decreases were partially offset by higher commodity prices. The variance between cash flows from operating activities and fund flows from operations is primarily due to non-cash working capital impacts of the windfall taxes payable.

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2022 vs. 2021

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Graphic

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Vermilion Energy Inc.  ■  Page 9  ■  2022 Management's Discussion and Analysis

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·For the year ended December 31, 2022, we recorded net earnings of $1,313.1 million compared $1,148.7 million for the comparable period in 2021. The increase in net earnings was primarily due to higher fund flows from operations driven by increased consolidated realized pricing and changes in our unrealized derivative position of $721.9 million driven by changes in the mark-to-market position. The increases were partially offset by lower impairment reversals recorded in 2022 of $144.4 million (net of $47.7 million deferred income tax expense), compared to impairment reversals recorded in 2021 of $987.1 million (net of $315.5 million deferred income tax expense).

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Graphic

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·For the year ended December 31, 2022 as compared to 2021, cash flows from operating activities increased by $979.8 million to $1,814.2 million and fund flows from operations increased by $715.0 million to $1,634.9 million. The increase in fund flows from operations were primarily driven by a 68% increase in our consolidated realized price from $66.81/boe to $111.95/boe and were partially offset by increased contributions to the jurisdictions we operate in the form of windfall taxes, increased current taxes, and increased royalties. The variance between cash flows from operating activities and fund flows from operations is primarily driven by non-cash working capital impact of the windfall taxes payable.

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Production review

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Q4 2022 vs. Q4 2021

· Consolidated average production of 85,450 boe/d in Q4 2022 increased slightly compared to Q4 2021 production of 84,417 boe/d. Production increased in Germany and Canada due to acquisitions in 2021 and 2022, respectively, as well as in Australia primarily due to new wells coming online in 2022. The increases were partially offset by natural decline in the Netherlands, France, and Ireland.

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2022 vs. 2021

· Consolidated average production of 85,187 boe/d in the year ended December 31, 2022 decreased slightly from 85,408 boe/d in the prior year comparative period. Production decreased in the Netherlands, France, and Ireland primarily due to natural decline. This was partially offset by an increase in Canada, Germany and the United States primarily due to acquisition activity in 2021 and 2022.

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Activity review

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● For the three months ended December 31, 2022, capital expenditures of $169.3 million were incurred.
● In our North America core region, we incurred capital expenditures of $113.9 million. In Canada, capital expenditures totaled $111.5 million as we drilled seven (5.5 net) wells, completed ten (6.9 net) wells, and brought on production twelve (6.7 net) wells in southeast Saskatchewan, and drilled twelve (10.6 net), completed ten (8.2 net), and brought on production seven (6.9 net) Mannville liquids-rich gas wells, we drilled one (1.0
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net) Mica well, and brought on production the wells on our first 6.0 (6.0 net) well Montney pad in Alberta. In the United States, $2.4 million was incurred primarily related to preparation for the 2023 drilling program which will commence in Q2 2023.
● In our International core region, capital expenditures of $55.4 million were incurred during Q4 2022. Our activities included $15.7 million incurred in France primarily on facilities and subsurface maintenance activities, $14.2 million incurred in the Netherlands primarily on drilling activities, and $10.1 million incurred in Germany primarily on drilling and facilities activity along with various other costs associated with support work for our Q4 2022 drilling campaign in Europe.
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Financial sustainability review

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Free cash flow

● Free cash flow of $1,083.0 million increased by $538.0 million for the year ended December 31, 2022 compared to the prior year period which was primarily driven by increased fund flows from operations on higher realized prices, partially offset by higher expenditure on drilling and development activities.

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Long-term debt and net debt

● Long-term debt decreased to $1.1 billion as at December 31, 2022 from $1.7 billion as at December 31, 2021 as a result of net repayments of $622.8 million, partially offset by unrealized foreign exchange losses of $50.8 million due to the US dollar strengthening.
● Net debt as at December 31, 2022 decreased to $1.3 billion from $1.6 billion at December 31, 2021 primarily due to decreases in long-term debt, partially offset by increases in income taxes payable as a result of $222.9 million of windfall taxes in Q4 2022.
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● The ratio of net debt to four quarter trailing fund flows from operations^(1)^ decreased to 0.8 as at December 31, 2022 (December 31, 2021 - 1.8) primarily due to higher four quarter trailing fund flows from operations.
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(1) Net debt to four quarter trailing fund flows from operations is a supplementary financial measure that does not have a standardized meaning under IFRS and therefore may not be comparable to similar measures presented by other issuers. It is calculated as net debt (capital measure) over the FFO from the preceding 4 quarters (total of segments measure). The measure is used to assess our ability to repay debt.

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Vermilion Energy Inc.  ■  Page 11  ■  2022 Management's Discussion and Analysis

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Benchmark Commodity Prices

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​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ **** ​ **** Q4/22 vs. **** ​ **** ​ **** 2022 vs. ****
​ Q4 2022 ​ Q4 2021 ​ Q4/21 ​ 2022 ​ 2021 ​ 2021 ****
Crude oil ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
WTI (/bbl) 112.24 97.21 16 % 122.62 85.14 44 %
WTI (US /bbl) 82.65 77.19 7 % 94.23 67.92 39 %
Edmonton Sweet index (/bbl) 109.85 93.30 18 % 120.25 80.27 50 %
Edmonton Sweet index (US /bbl) 80.89 74.09 9 % 92.41 64.03 44 %
Saskatchewan LSB index (/bbl) 106.05 92.90 14 % 118.22 80.12 48 %
Saskatchewan LSB index (US /bbl) 78.09 73.77 6 % 90.85 63.91 42 %
Canadian C5+ Condensate index (/bbl) 113.19 99.65 14 % 121.96 85.50 43 %
Canadian C5+ Condensate index (US /bbl) 83.35 79.13 5 % 93.72 68.20 37 %
Dated Brent (/bbl) 120.47 100.40 20 % 131.68 88.67 49 %
Dated Brent (US /bbl) 88.71 79.73 11 % 101.19 70.73 43 %
Natural gas ​ ​ ​ ​ ​
North America ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
AECO 5A (/mcf) 4.64 4.66 — % 5.25 3.62 45 %
Henry Hub (/mcf) 8.50 7.34 16 % 8.67 4.82 80 %
Henry Hub (US /mcf) 6.26 5.83 7 % 6.66 3.85 73 %
Europe(1) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
NBP Day Ahead (/mmbtu) 26.09 ​ 37.76 ​ (31) % 31.78 ​ 19.62 ​ 62 %
NBP Month Ahead (/mmbtu) 43.51 ​ 41.00 ​ 6 % 41.44 ​ 20.61 ​ 101 %
NBP Day Ahead (/mmbtu) 18.82 ​ 26.21 ​ (28) % 23.21 ​ 13.22 ​ 76 %
NBP Month Ahead (/mmbtu) 31.38 ​ 28.46 ​ 10 % 30.26 ​ 13.89 ​ 118 %
TTF Day Ahead (/mmbtu) 38.36 ​ 38.86 ​ (1) % 48.35 ​ 19.86 ​ 144 %
TTF Month Ahead (/mmbtu) 49.98 40.25 24 % 52.59 20.35 158 %
TTF Day Ahead (/mmbtu) 27.67 26.97 3 % 35.30 13.39 164 %
TTF Month Ahead (/mmbtu) 36.05 27.94 29 % 38.40 13.72 180 %
Average exchange rates ​ ​ ​ ​
CDN /US 1.36 1.26 8 % 1.30 1.25 ​ 4 %
CDN /Euro 1.39 1.44 (4) % 1.37 1.48 (7) %
Realized prices ​ ​ ​ ​
Crude oil and condensate (/bbl) 115.02 96.88 19 % 123.89 83.78 48 %
NGLs (/bbl) 39.93 47.27 (16) % 45.95 34.44 33 %
Natural gas (/mcf) 17.43 17.89 (3) % 18.99 9.53 99 %
Total (/boe) 103.99 96.82 7 % 111.95 66.81 68 %

All values are in US Dollars.

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^(1)^ NBP and TTF pricing can occur on a day-ahead ("DA") or month-ahead ("MA") basis. DA prices in a period reflect the average current day settled price on the next days' delivery and MA prices in a period represent daily one month futures contract prices which are determined at the end of each month. In a rising price environment, the DA price will tend to be greater than the MA price and vice versa. Natural gas in the Netherlands and Germany is benchmarked to the TTF and production is generally equally split between DA and MA contracts. Natural gas in Ireland is benchmarked to the NBP and is sold on DA contracts.

​

As an internationally diversified producer, we are exposed to a range of commodity prices. In our North America core region, our crude oil is sold at benchmarks linked to WTI (including the Edmonton Sweet index, the Saskatchewan LSB index, and the Canadian C5+ index) and our natural gas is

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sold at benchmarks linked to the AECO index (in Canada) or the Henry Hub ("HH") index (in the United States). In our International core region, our crude oil is sold with reference to Dated Brent and our natural gas is sold with reference to NBP, TTF, or indices highly correlated to TTF.

​

Graphic

​

● Crude oil prices increased in Q4 2022 relative to Q4 2021 as reduced spare capacity and increased geopolitical supply risks outweighed the incremental demand concerns regarding tighter monetary policies and global recession risks. Canadian dollar WTI and Brent prices rose 16% and 20%, respectively in Q4 2022 relative to Q4 2021.
● In Canadian dollar terms, year-over-year, the Edmonton Sweet differential narrowed by $1.42/bbl to a discount of $2.49/bbl against WTI, and the Saskatchewan LSB differential widened by $1.88/bbl to a discount of $6.19/bbl against WTI.
--- ---
● Approximately 39% of Vermilion’s Q4 2022 crude oil and condensate production was priced at the Dated Brent index, which averaged a premium to WTI of US$6.06/bbl, while the remainder of our crude oil and condensate production was priced at the Saskatchewan LSB, Canadian C5+, Edmonton Sweet, and WTI indices.
--- ---

​

Graphic

​

● In Canadian dollar terms, year-over-year, prices for European natural gas linked to NBP and TTF decreased by 31% and 1% respectively on a day-ahead basis. On a month ahead basis, NBP and TTF rose by 6% and 24% respectively. While prices were off their Q3 2022 highs, they

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remained slightly elevated compared to historical trends due to Russian pipeline supply decreases, elevated winter risk premium, and requirement to attract increased LNG imports.
● Natural gas prices in Canadian dollar terms at NYMEX HH increased by 16% while AECO remained flat. NYMEX HH prices benefited from temporary weather related demand increases and limited production growth in the second half of 2022. AECO year-over-year price changes were limited compared to NYMEX as basis widened on high WCSB production growth and storage levels returning to within their 5 year range levels.
--- ---
● For Q4 2022, average European natural gas prices represented a $34.85/mcf premium to AECO. Approximately 34% of our natural gas production in Q4 2022 benefited from this premium European pricing.
--- ---

​

Graphic

​

● For the three months ended December 31, 2022, the Canadian dollar strengthened 4% against the Euro compared to Q4 2021.
● For the three months ended December 31, 2022, the Canadian dollar weakened 8% against the US Dollar compared to Q4 2021.
--- ---

​

​

North America

​

​ ​ ​ ​ ​ ​ ​ ​ ​
​ **** Q4 2022 **** Q4 2021 **** 2022 **** 2021
Production ^(1)^
Crude oil and condensate (bbls/d) **** 25,291 23,846 **** 24,393 24,390
NGLs (bbls/d) **** 7,497 8,461 **** 7,961 8,325
Natural gas (mmcf/d) **** 154.26 137.93 **** 151.30 144.87
Total production volume (boe/d) **** 58,499 55,295 **** 57,571 56,858

​

^(1)^Please refer to Supplemental Table 4 "Production" for disclosure by product type.

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ **** Q4 2022 **** Q4 2021 2022 2021
​ ​ M $/boe ​ M $/boe ​ M $/boe ​ M $/boe
Sales **** 360,295 66.95 ​ 305,054 59.97 **** 1,510,517 71.88 1,014,190 48.87
Royalties **** (50,945) (9.47) (47,119) (9.26) **** (240,432) (11.44) (144,398) (6.96)
Transportation **** (13,014) (2.42) (9,447) (1.86) **** (45,467) (2.16) (40,100) (1.93)
Operating **** (72,694) (13.51) (59,425) (11.68) **** (268,271) (12.77) (232,370) (11.20)
General and administration ^(1)^ **** 513 0.10 (10,224) (2.01) **** (20,651) (0.98) (27,887) (1.34)
Corporate income tax expense ^(1)^ ​ (712) (0.13) ​ 2,140 0.42 ​ (1,011) (0.05) ​ 1,451 0.07
Fund flows from operations **** 223,443 41.52 180,979 35.58 **** 934,685 44.48 570,886 27.51
Drilling and development **** (113,892) ​ **** (89,643) ​ (338,556) ​ (222,782) ​
Free cash flow **** 109,551 ​ **** 91,336 ​ 596,129 ​ 348,104 ​

All values are in US Dollars.

​

^(1)^Includes amounts from Corporate segment.

​

Production from our North American operations averaged 58,499 boe/d in Q4 2022, an increase of 2% from the prior quarter primarily due to new well production from our Montney assets in Canada and a full quarter contribution from our 2022 drilling program in the United States. In Alberta, we drilled twelve (10.6 net), completed ten (8.2 net), and brought on production seven (6.9 net) Mannville liquids rich gas wells, while at Mica we drilled one (1.0 net) well and brought on production the six (6.0 net) wells from our first Montney pad. The six well Montney pad was brought on production in late November and saw rates increase through the balance of the year as the wells cleaned up. Total production from our Montney assets averaged 7,500

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boe/d during the month of December. In December, drilling commenced on a follow up three-well pad in Alberta which is expected to be completed and tied in during the first half of 2023. During the fourth quarter we received three permits in British Columbia, including one of the permits to construct a 16,000 boe/d battery and drill a multi-well pad in British Columbia. We also signed agreements to acquire 11 sections of adjacent land at Mica, further consolidating our contiguous land base and increasing our Tier 1 inventory.

​

In Saskatchewan, we drilled seven (5.5 net) wells, completed ten (6.9 net) wells, and brought on production twelve (6.7 net) wells in southeast Saskatchewan. No drilling or completion activity occurred in the United States in the fourth quarter as the team focused on preparation for the 2023 drilling program which will commence in Q2 2023.

​

Sales

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ **** Q4 2022 **** Q4 2021 2022 2021
​ ​ M $/boe ​ M $/boe ​ M $/boe ​ M $/boe
Canada **** 315,897 65.13 270,600 59.16 **** 1,344,284 70.33 901,775 47.54
United States **** 44,398 83.51 34,454 67.18 **** 166,233 87.46 112,415 62.98
North America **** 360,295 66.95 305,054 59.97 **** 1,510,517 71.88 1,014,190 48.87

All values are in US Dollars.

​

Sales in North America increased on a dollar and per unit basis for the three months and year ended December 31, 2022 versus the comparable prior periods due to significantly higher realized prices across all products coupled with slightly higher production primarily related to acquisition activity.

​

Royalties

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ **** Q4 2022 **** Q4 2021 2022 2021
​ ​ M $/boe ​ M $/boe ​ M $/boe ​ M $/boe
Canada **** (38,747) (7.99) (37,064) (8.10) **** (196,005) (10.26) (113,651) (5.99)
United States **** (12,198) (22.94) (10,055) (19.60) **** (44,427) (23.38) (30,747) (17.23)
North America **** (50,945) (9.47) (47,119) (9.26) **** (240,432) (11.44) (144,398) (6.96)

All values are in US Dollars.

​

Royalties in North America increased on a dollar and per unit basis for the three months and year ended December 31, 2022 versus the comparable prior periods primarily due to increased sliding scale royalties driven by higher commodity prices. Royalties as a percentage of sales for the three months and year ended December 31, 2022 were 14.1% and 15.9%, respectively, compared to the prior year comparative periods of 15.4% and 14.2% respectively.

​

Transportation

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ **** Q4 2022 **** Q4 2021 2022 2021
​ ​ M $/boe ​ M $/boe ​ M $/boe ​ M $/boe
Canada **** (12,919) (2.66) (9,134) (2.00) **** (44,849) (2.35) (38,764) (2.04)
United States **** (95) (0.18) **** (313) (0.61) **** (618) (0.33) (1,336) (0.75)
North America **** (13,014) (2.42) (9,447) (1.86) **** (45,467) (2.16) (40,100) (1.93)

All values are in US Dollars.

​

Transportation expense in North America increased on a dollar and per boe basis for the three months and year ended December 31, 2022 versus the comparable prior period primarily due to increased tariffs in Saskatchewan beginning in mid-2022.

​

Operating expense

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ **** Q4 2022 **** Q4 2021 2022 2021
​ ​ M $/boe ​ M $/boe ​ M $/boe ​ M $/boe
Canada **** (63,305) (13.05) (54,695) (11.96) **** (240,899) (12.60) (215,378) (11.35)
United States **** (9,389) (17.66) (4,730) (9.22) **** (27,372) (14.40) (16,992) (9.52)
North America **** (72,694) (13.51) (59,425) (11.68) **** (268,271) (12.77) (232,370) (11.20)

All values are in US Dollars.

​

Operating expenses in North America increased on a dollar basis and per boe basis for the three months and year ended December 31, 2022 versus the comparable prior periods. In Canada, increases during the three months ended December 31, 2022 were primarily the result of an increase in downhole, trucking and project expenses related to our Mica assets, as well as processing fees due to higher plant rates in Saskatchewan. Increases

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during the year ended December 31, 2022 were primarily the result of acquisition activity, planned maintenance, and downhole costs. In the United States, increases during the three months and year ended December 31, 2022 were primarily downhole costs and inflationary pressures.

​

​

International

​

​ ​ ​ ​ ​ ​ ​ ​ ​
​ **** Q4 2022 **** Q4 2021 **** 2022 **** 2021
Production ^(1)^ **** **** **** ****
Crude oil and condensate (bbls/d) **** 13,624 12,419 **** 13,135 13,753
Natural gas (mmcf/d) **** 79.97 100.22 **** 86.88 88.77
Total production volume (boe/d) **** 26,953 29,123 **** 27,616 28,548
Total sales volume (boe/d) **** 29,585 30,689 **** 27,506 28,430

​

^(1)^Please refer to Supplemental Table 4 "Production" for disclosure by product type.

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Q4 2022 Q4 2021 2022 2021
​ **** M /boe M /boe M /boe M $/boe
Sales **** 482,398 177.23 460,861 163.23 1,965,877 195.81 1,065,571 102.69
Royalties **** (17,358) (6.38) (11,666) (4.13) (65,585) (6.53) (41,724) (4.02)
Transportation **** (8,962) (3.29) (9,586) (3.40) (33,429) (3.33) (37,061) (3.57)
Operating **** (63,553) (23.35) (53,255) (18.86) (220,763) (21.99) (180,643) (17.41)
General and administration **** (13,857) (5.09) (7,150) (2.53) (37,026) (3.69) (24,990) (2.41)
Corporate income tax expense **** (41,246) (15.15) (34,374) (12.17) (207,142) (20.63) (31,617) (3.05)
PRRT **** (5,045) (1.85) (5,544) (1.96) (18,318) (1.82) (15,688) (1.51)
Fund flows from operations **** 332,377 122.12 339,286 120.18 1,383,614 137.82 733,848 70.72
Drilling and development **** (43,957) ​ (29,359) ​ (189,500) ​ (116,608)
Exploration and evaluation ​ (11,456) ​ (26,805) ​ (23,761) ​ (35,406) ​
Free cash flow **** 276,964 ​ 283,122 ​ 1,170,353 ​ 581,834

All values are in US Dollars.

​

Production from our International operations averaged 26,953 boe/d in Q4 2022, a decrease of 1% from the prior quarter, primarily due to natural decline in Netherlands and Germany, as well as lower than anticipated production in Australia due to unplanned downtime. This was largely offset by higher production in France and Ireland. Production from the fire-related downtime in France was gradually restored through the fourth quarter of 2022 and has been fully restored subsequent to year end. Ireland production increased 1% in Q4 2022 compared to the previous quarter as the Corrib facility experienced strong operational run time during the quarter.

​

During the fourth quarter we drilled one (1.0 net) oil well in Germany, which was brought on production in Q1 2023. We also continued to advance our deep well gas exploration and development plans in Germany as we prepare for our first well to be drilled in the fourth quarter of 2023. In the Netherlands, we drilled one (0.5 net) gas well which encountered a 19 metre gas column and is expected to be brought on production in the first half of 2023. We drilled two (2.0 net) exploratory wells in Croatia, however, neither of the wells encountered commercial hydrocarbons.

​

Sales

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Q4 2022 Q4 2021 2022 2021
​ **** M /boe M /boe M /boe M $/boe
Australia **** 95,420 139.95 40,332 112.26 221,187 148.15 143,014 103.01
France **** 77,910 119.68 79,809 100.18 365,431 132.90 279,263 88.15
Netherlands **** 119,668 281.75 165,370 205.17 562,857 279.87 295,723 110.47
Germany **** 121,011 218.13 65,623 164.96 481,260 231.34 131,935 98.06
Ireland **** 64,753 162.16 109,352 236.78 324,345 194.05 214,425 120.51
Central and Eastern Europe **** 3,636 356.05 375 203.80 10,797 313.02 1,211 65.06
International **** 482,398 177.23 460,861 163.23 1,965,877 195.81 1,065,571 102.69

All values are in US Dollars.

​

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As a result of changes in inventory levels, our sales volumes for crude oil in Australia, France, and Germany may differ from our production volumes in those business units. The following table provides the crude oil sales volumes (consisting entirely of "light crude oil and medium crude oil") for those jurisdictions.

​

​ ​ ​ ​ ​ ​ ​ ​ ​
Crude oil sales volumes (bbls/d) **** Q4 2022 **** Q4 2021 **** 2022 **** 2021
Australia **** 7,411 3,905 **** 4,090 3,804
France **** 7,076 8,659 **** 7,533 8,680
Germany **** 1,721 1,324 **** 1,337 1,051
International ​ 16,208 ​ 13,888 ​ 12,960 ​ 13,535

​

Sales increased on a dollar and per boe basis for the three months and year ended December 31, 2022 versus the comparable prior periods due to higher realized prices across Australia, France, Netherlands, Germany and Central and Eastern Europe business units and higher sales volume in Australia and Germany due to new wells coming online and acquisition activity. These increases were partially offset by lower realized price for the three month period in Ireland and lower sales volumes in France, Netherlands, and Ireland, due to natural decline combined with the timing of liftings in France.

​

Royalties

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Q4 2022 **** Q4 2021 2022 2021
​ **** M $/boe ​ M /boe M /boe M $/boe
France **** (9,294) (14.28) (10,174) (12.77) (40,353) (14.68) (37,666) (11.89)
Netherlands **** (512) (1.21) (419) (0.52) (512) (0.25) (873) (0.33)
Germany **** (6,403) (11.54) (909) (2.29) (21,232) (10.21) (2,847) (2.12)
Central and Eastern Europe **** (1,149) (112.51) (164) (89.13) (3,488) (101.12) (338) (18.16)
International **** (17,358) (6.38) (11,666) (4.13) (65,585) (6.53) (41,724) (4.02)

All values are in US Dollars.

​

Royalties in our International core region are primarily incurred in France and Germany, where royalties include charges based on a percentage of sales and fixed per boe charges. Our production in Australia and Ireland is not subject to royalties.

​

Royalties increased on a dollar and per unit basis for the three months and year ended December 31, 2022 versus the comparable prior periods primarily due to higher sales prices.

​

Royalties as a percentage of sales for the three months ended December 31, 2022 of 3.6% increased versus the comparable prior period of 2.5% primarily due to an increase in royalty rate in Germany. Royalties as a percentage of sales for the year ended December 31, 2022 of 3.3% decreased versus the prior year comparable period of 3.9% primarily due to higher sales in business units that are not subject to royalties.

​

Transportation

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Q4 2022 Q4 2021 2022 2021
​ **** M /boe M /boe M /boe M $/boe
France **** (4,589) (7.05) (6,574) (8.25) (20,100) (7.31) (26,497) (8.36)
Germany **** (3,621) (6.53) (2,076) (5.22) (9,751) (4.69) (6,359) (4.73)
Ireland **** (752) (1.88) (936) (2.03) (3,578) (2.14) (4,205) (2.36)
International **** (8,962) (3.29) (9,586) (3.40) (33,429) (3.33) (37,061) (3.57)

All values are in US Dollars.

​

Transportation expense decreased for the three months and year ended December 31, 2022 versus the comparable prior periods. This was primarily due to the lower volume of liftings in France, partially offset by increased volumes in Germany. On a per unit basis, transportation expense remained relatively flat versus prior year comparable periods.

​

Our production in Australia, Netherlands and Central and Eastern Europe is not subject to transportation expense.

​

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Operating expense

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Q4 2022 Q4 2021 2022 2021
​ **** $M ​ /boe $M ​ /boe $M ​ /boe $M ​ $/boe
Australia **** (21,291) **** (31.23) (15,918) (44.31) (57,478) **** (38.50) (50,748) (36.55)
France **** (12,638) **** (19.41) (14,242) (17.88) (57,588) **** (20.94) (52,147) (16.46)
Netherlands **** (11,229) **** (26.44) (11,449) (14.20) (45,903) **** (22.82) (35,269) (13.17)
Germany **** (13,292) **** (23.96) (7,323) (18.41) (41,523) **** (19.96) (27,149) (20.18)
Ireland **** (4,687) **** (11.74) (4,107) (8.89) (16,580) **** (9.92) (14,889) (8.37)
Central and Eastern Europe **** (416) **** (40.74) (216) (117.39) (1,691) **** (49.03) (441) (23.69)
International **** (63,553) **** (23.35) (53,255) (18.86) (220,763) **** (21.99) (180,643) (17.41)

All values are in US Dollars.

​

For the three months ended December 31, 2022 versus the prior comparable period, operating expense increased on a dollar and per boe basis primarily due to asset integrity costs in Australia, increased maintenance activity and electricity charges in Germany, partially offset by a decrease in France due to a rate recovery on previous period electricity charges. Operating expense increased on a dollar and per boe basis for the year ended December 31, 2022 versus the prior year comparable period primarily due to the impact of higher fuel and electricity prices in Europe and increased costs in Germany due to 2021 acquisition activity.

​

​

Consolidated Financial Performance Review

​

​ ​ ​ ​ ​ ​
(M except per share) Dec 31, 2022 **** Dec 31, 2021 **** Dec 31, 2020
Total assets 6,991,058 ​ 5,905,323 ​ 4,109,139
Long-term debt 1,081,351 1,651,569 1,933,848
Petroleum and natural gas sales 3,476,394 2,079,761 1,119,545
Net earnings (loss) 1,313,062 1,148,696 (1,517,427)
Net earnings (loss) per share ​ ​ ​
Basic 8.03 7.13 (9.61)
Diluted 7.80 6.97 (9.61)
Cash dividends (/share) 0.28 — 0.58

All values are in US Dollars.

​

Vermilion Energy Inc.  ■  Page 18  ■  2022 Management's Discussion and Analysis

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Financial performance

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Q4 2022 Q4 2021 2022 2021
​ **** M /boe M /boe M /boe M $/boe
Sales **** 842,693 103.99 765,915 96.82 3,476,394 111.95 2,079,761 66.81
Royalties **** (68,303) (8.43) (58,785) (7.43) (306,017) (9.85) (186,122) (5.98)
Transportation **** (21,976) (2.71) (19,033) (2.41) (78,896) (2.54) (77,161) (2.48)
Operating **** (136,247) (16.81) (112,680) (14.24) (489,034) (15.75) (413,013) (13.27)
General and administration **** (13,344) (1.65) (17,374) (2.20) (57,677) (1.86) (52,877) (1.70)
Corporate income tax expense **** (41,958) (5.18) (32,234) (4.07) (208,153) (6.70) (30,166) (0.97)
Windfall taxes ​ (222,859) (27.50) — — (222,859) (7.18) — —
PRRT **** (5,045) (0.62) (5,544) (0.70) (18,318) (0.59) (15,688) (0.50)
Interest expense **** (22,506) (2.78) (16,279) (2.06) (82,858) (2.67) (73,075) (2.35)
Realized loss on derivatives **** (43,940) (5.42) (189,598) (23.97) (405,894) (13.07) (327,384) (10.52)
Realized foreign exchange gain (loss) **** 18,845 2.33 (2,395) (0.30) 15,195 0.49 (6,613) (0.21)
Realized other (expense) income **** (1,140) (0.14) 10,180 1.29 12,982 0.42 22,200 0.71
Fund flows from operations **** 284,220 35.08 322,173 40.73 1,634,865 52.65 919,862 29.54
Equity based compensation ​ (5,377) ​ (6,666) ​ (44,390) ​ (41,565) ​
Unrealized gain (loss) on derivative instruments ^(1)^ ​ 549,693 ​ 172,265 ​ 540,801 ​ (181,094) ​
Unrealized foreign exchange (loss) gain ^(1)^ ​ (47,405) ​ 7,122 ​ (84,464) ​ (64,963) ​
Accretion ​ (16,501) ​ (10,983) ​ (58,170) ​ (43,552) ​
Depletion and depreciation ​ (171,926) ​ (148,216) ​ (577,134) ​ (571,688) ​
Deferred tax expense ​ (196,733) ​ (14,834) ​ (288,707) ​ (187,343) ​
Gain on business combinations ​ — ​ — ​ — ​ 17,198 ​
Impairment reversal ​ — ​ 23,922 ​ 192,094 ​ 1,302,619 ​
Unrealized other expense ^(1)^ ​ (563) ​ (195) ​ (1,833) ​ (778) ​
Net earnings ​ 395,408 ​ 344,588 ​ 1,313,062 ​ 1,148,696 ​

All values are in US Dollars.

​

(1) Unrealized gain (loss) on derivative instruments, Unrealized foreign exchange (loss) gain, and Unrealized other expense are line items from the respective Consolidated Statements of Cash Flows.

​

Fluctuations in fund flows from operations may occur as a result of changes in production levels, commodity prices, and costs to produce petroleum and natural gas. In addition, fund flows from operations may be affected by the timing of crude oil shipments in Australia and France. When crude oil inventory is built up, the related operating expense, royalties, and depletion expense are deferred and carried as inventory on the consolidated balance sheet. When the crude oil inventory is subsequently drawn down, the related expenses are recognized within profit or loss.

​

General and administration

● General and administration expense decreased in Q4 2022 versus Q4 2021 primarily due to lower discretionary headcount costs.
● General and administration expense increased for the year ended December 31, 2022 versus the prior year comparable period primarily due to higher legal, tax, and financial advisory costs.
--- ---

​

PRRT and corporate income taxes

● PRRT remained relatively consistent for the three months ended December 31, 2022 versus the comparable prior period. PRRT increased for the year ended December 31, 2022 versus the prior year comparable period due to higher sales partially offset by higher capital expenditures in the current period.
● Corporate income taxes for the three months and year ended December 31, 2022 increased versus the comparable prior periods primarily due to higher taxable income as a result of increased commodity prices in 2022.
--- ---

​

Windfall taxes

● On September 30, 2022 the Council of the European Union and member states agreed to a set mandatory temporary solidarity contribution on the profits of oil and gas producers. The contribution set out minimum amounts to be calculated on taxable profits starting in 2022 and/or 2023, which are above a 20% increase of the average yearly taxable profits for 2018 to 2021. Legislation became substantively enacted during the fourth quarter of 2022 resulting in a full year of windfall taxes being booked during the fourth quarter.
● Windfall taxes recorded in 2022 are based on the rates legislated or, in the case of Ireland, announced as of December 31, 2022. In Netherlands, Germany, and France, a rate of 33% has been legislated on excess profits and a rate of 75% has been announced by the Irish Government. For the three months ended and year ended December 31, 2022, windfall tax expense was $222.9 million.
--- ---

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​

Interest expense

● Interest expense increased for the three months and year ended December 31, 2022 compared to the comparable prior periods despite lower debt levels. This was due to higher variable interest rates and an increase in the percentage of our debt with fixed interest rates following the issuance of the 2030 senior unsecured notes.

​

Realized gain or loss on derivatives

● For the three months and year ended December 31, 2022, we recorded realized losses on our crude oil and natural gas hedges due to higher commodity pricing compared to the strike prices on our hedges.
● A listing of derivative positions as at December 31, 2022 is included in “Supplemental Table 2” of this MD&A.
--- ---

​

Realized other income

● Realized other income for the three months and year ended December 31, 2022 decreased versus the comparable prior periods primarily due to amounts for funding under the Saskatchewan Accelerated Site Closure program to complete abandonment and reclamation on inactive oil and gas wells and facilities.

​

Net earnings

​

Fluctuations in net earnings from period-to-period are caused by changes in both cash and non-cash based income and charges. Cash based items are reflected in fund flows from operations. Non-cash items include: equity based compensation expense, unrealized gains and losses on derivative instruments, unrealized foreign exchange gains and losses, accretion, depletion and depreciation expense, and deferred taxes. In addition, non-cash items may also include gains resulting from business combinations or charges resulting from impairment or impairment reversals.

​

Equity based compensation

Equity based compensation expense relates primarily to non-cash compensation expense attributable to long-term incentives granted to directors, officers, and employees under security-based arrangements. Equity based compensation expense decreased for the three months ended December 31, 2022 versus the comparable prior period primarily due to the lower value of LTIP awards outstanding in the current period. For the year ended December 31, 2022 versus the prior year comparable period, equity based compensation expense increased primarily due to higher bonuses under the employee bonus plan during the current year.

​

Unrealized gain or loss on derivative instruments

Unrealized gain or loss on derivative instruments arises as a result of changes in forecasts for future prices and rates. As Vermilion uses derivative instruments to manage the commodity price exposure of our future crude oil and natural gas production, we will normally recognize unrealized gains on derivative instruments when future commodity price forecasts decline and vice-versa. As derivative instruments are settled, the unrealized gain or loss previously recognized is reversed, and the settlement results in a realized gain or loss on derivative instruments.

​

USD-to-CAD cross currency interest rate swaps and foreign exchange swaps may be entered into to hedge the foreign exchange movements on USD borrowings on our revolving credit facility. As such, unrealized gains and losses on our cross currency interest swaps are offset by unrealized losses and gains on foreign exchange relating to the underlying USD borrowings from our revolving credit facility.

​

For the three months ended December 31, 2022, we recognized a net unrealized gain on derivative instruments of $549.7 million. This consists of unrealized gains of $573.4 million on our European natural gas commodity derivative instruments, $10.9 million on our North American natural gas commodity derivative instruments, and $4.2 million on our crude oil commodity derivative instruments, partially offset by unrealized losses of $21.0 million on our equity swaps and $17.8 million on our USD-to-CAD foreign exchange swaps.

​

For the year ended December 31, 2022, we recognized a net unrealized gain on derivative instruments of $540.8 million. This consists of unrealized gains of $509.1 million on our European natural gas commodity derivative instruments, $30.4 million on our equity swaps, $9.9 million on our crude oil commodity derivative instruments, and $5.6 million on our North American natural gas commodity derivative instruments, partially offset by unrealized losses of $14.2 million on our USD-to-CAD foreign exchange swaps.

​

Unrealized foreign exchange gains or losses

As a result of Vermilion’s international operations, Vermilion has monetary assets and liabilities denominated in currencies other than the Canadian dollar. These monetary assets and liabilities include cash, receivables, payables, long-term debt, derivative instruments and intercompany loans. Unrealized foreign exchange gains and losses result from translating these monetary assets and liabilities from their underlying currency to the Canadian dollar.

​

Vermilion Energy Inc.  ■  Page 20  ■  2022 Management's Discussion and Analysis

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In 2022, unrealized foreign exchange gains and losses primarily resulted from:

● The translation of Euro denominated intercompany loans from our international subsidiaries to Vermilion Energy Inc. An appreciation in the Euro against the Canadian dollar will result in an unrealized foreign exchange loss (and vice-versa). Under IFRS, the offsetting foreign exchange loss or gain is recorded as a currency translation adjustment within other comprehensive income. As a result, consolidated comprehensive income reflects the offsetting of these translation adjustments while net earnings reflects only the parent company's side of the translation.
● The translation of USD borrowings on our revolving credit facility. The unrealized foreign exchange gains or losses on these borrowings are offset by unrealized derivative gains or losses on associated USD-to-CAD cross currency interest rate swaps (discussed further below).
--- ---
● The translation of our USD denominated 2025 senior unsecured notes and USD denominated 2030 senior unsecured notes. During the period between June 12, 2019 and May 5, 2020 the USD 2025 senior unsecured notes were hedged by a USD-to-CAD cross currency interest rate swap. Subsequent to the termination of these instruments, amounts previously recognized in the hedge accounting reserve will be recognized into earnings through unrealized foreign exchange loss over the period of the hedged cash flows.
--- ---

​

For the three months ended December 31, 2022, we recognized a net unrealized foreign exchange loss of $47.4 million, driven by an unrealized loss of $73.1 million on intercompany loans due to the Euro strengthening 8.0% against the Canadian dollar in Q4 2022. This was partially offset by an unrealized gain of $15.6 million on our USD borrowings from our revolving credit facility as well as an unrealized gain of $11.2 million on our senior unsecured notes resulting from the US dollar weakening 1.2% against the Canadian dollar in Q4 2022.

​

For the year ended December 31, 2022, we recognized a net unrealized foreign exchange loss of $84.5 million, driven by an unrealized loss of $55.0 million on our senior unsecured notes resulting from the US dollar strengthening 6.8% against the Canadian dollar in 2022, as well as unrealized losses of $27.0 million on intercompany loans due to the Euro strengthening 0.5% against the Canadian dollar in 2022, with the majority of the unrealized loss driven by the significant Q4 strengthening of the Euro. This was partially offset by unrealized gains of $4.3 million on our USD borrowings from our revolving credit facility.

​

As at December 31, 2022, a $0.01 appreciation of the Euro against the Canadian dollar would result in a $5.6 million decrease to net earnings as a result of an unrealized loss on foreign exchange, while a $0.01 appreciation of the US dollar against the Canadian dollar would result in a $5.4 million decrease to net earnings as a result of an unrealized loss on foreign exchange.

​

Accretion

Accretion expense is recognized to update the present value of the asset retirement obligation balance. For the three months and year ended December 31, 2022, accretion expense increased versus the comparable prior periods primarily due to the impact of a higher asset retirement obligation balance at the end of 2022 compared to 2021 and slight strengthening of the Euro against the Canadian dollar.

​

Depletion and depreciation

Depletion and depreciation expense is recognized to allocate the cost of capital assets over the useful life of the respective assets. Depletion and depreciation expense per unit of production is determined for each depletion unit (which are groups of assets within a specific production area that have similar economic lives) by dividing the sum of the net book value of capital assets and future development costs by total proved plus probable reserves.

​

Fluctuations in depletion and depreciation expense are primarily the result of changes in produced crude oil and natural gas volumes, and changes in depletion and depreciation per unit. Fluctuations in depletion and depreciation per unit are the result of changes in reserves, depletable base (net book value of capital assets and future development costs), and relative production mix.

​

Depletion and depreciation on a per boe basis for the three months and year ended December 31, 2022 of $21.22 and $18.59, respectively increased from $18.74 and $18.36 in the comparable prior periods primarily due to a higher depletable base due to impairment reversals in 2021 and 2022, acquisitions, and the strengthening of the Euro against the Canadian dollar in Q4 2022.

​

Deferred tax

Deferred tax assets arise when the tax basis of an asset exceeds its accounting basis (known as a deductible temporary difference). Conversely, deferred tax liabilities arise when the tax basis of an asset is less than its accounting basis (known as a taxable temporary difference). Deferred tax assets are recognized only to the extent that it is probable that there are future taxable profits against which the deductible temporary difference can be utilized. Deferred tax assets and liabilities are measured at the enacted or substantively enacted tax rate that is expected to apply when the asset is realized, or the liability is settled.

​

As such, fluctuations in deferred tax expenses and recoveries primarily arise as a result of: changes in the accounting basis of an asset or liability without a corresponding tax basis change (e.g. when derivative assets and liabilities are marked-to-market or when accounting depletion differs from tax depletion), changes in available tax losses (e.g. if they are utilized to offset taxable income), changes in estimated future taxable profits resulting in a derecognition or recognition of deferred tax assets, and changes in enacted or substantively enacted tax rates.

Vermilion Energy Inc.  ■  Page 21  ■  2022 Management's Discussion and Analysis

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​

For the three months and year ended December 31, 2022, the Company recorded deferred tax expense of $196.7 million and $288.7 million, respectively, compared to deferred tax expense of $14.8 million and $187.3 million, respectively, for the comparable prior periods. The deferred tax expense for the three months ended and year ended December 31, 2022 was primarily due to loss utilization on increased taxable income, as well as the tax impact on unrealized derivative movement.

​

Impairment

Impairment losses or reversals of losses are recognized when indicators of impairment or impairment reversal arise and the carrying amount of a cash generating unit ("CGU") is greater than (impairment) or less than (impairment reversal) its recoverable amount, determined as the higher of fair value less costs of disposal or value-in-use. Subsequent to the first quarter of 2022 there were no indicators of impairment and no amounts relating to previous impairments remaining to be reversed.

​

In the first quarter of 2022, indicators of impairment reversal were present in our Canada - Saskatchewan and France - Neocomian CGUs due to an increase in forecast oil prices. As a result of the indicators of impairment reversal, the Company performed impairment reversal calculations on the identified CGUs and the recoverable amounts were determined using fair value less costs to sell, which considered future after-tax cash flows from proved plus probable reserves and an after-tax discount rate of 12.0%. Based on the results of the impairment reversal calculations completed, recoverable amounts were determined to be greater than the carrying values of the CGUs tested and $144.4 million (net of $47.7 million deferred income tax expense) of impairment reversal was recorded.

​

Inputs used in the measurement of capital assets are not based on observable market data and fall within level 3 of the fair value hierarchy.

​

​

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Taxes

​

Current income tax rates

​

Vermilion typically pays corporate income taxes in France, Netherlands, Australia and Germany. In addition, Vermilion pays PRRT in Australia which is a profit based tax applied at a rate of 40% on sales less operating expenses, capital expenditures, and other eligible expenditures. PRRT is deductible in the calculation of taxable income in Australia.

​

For 2022 and 2021, taxable income was subject to corporate income tax at the following statutory rates:

​

​ ​ ​ ​ ​ ​
Jurisdiction **** 2022 **** 2021 ****
Canada 24.6 % 24.6 %
United States 21.0 % 21.0 %
France 25.8 % 27.4 %
Netherlands ^(1)^ 50.0 % 50.0 %
Germany 31.3 % 31.4 %
Ireland 25.0 % 25.0 %
Australia 30.0 % 30.0 %

​

^(1)^ In the Netherlands, an additional 10% uplift deduction is allowed against taxable income that is applied to operating expenses, eligible general and administration expenses, and tax deductions for depletion and abandonment retirement obligations.

​

Windfall Taxes

​

On September 30, 2022 the Council of the European Union and member states agreed to a set mandatory temporary solidarity contribution on the profits of oil and gas producers. The contribution set out minimum amounts to be calculated on taxable profits starting in 2022 and/or 2023, which are above a 20% increase of the average yearly taxable profits for 2018 to 2021 period. Legislation became substantively enacted during the fourth quarter of 2022 resulting in a full year of windfall taxes being booked during the fourth quarter.

​

Windfall tax rates apply to taxable profits which are above a 20% increase of the average yearly profits for the 2018 to 2021 period. The following rates have been legislated as of December 31, 2022:

​

​ ​ ​ ​ ​ ​
Jurisdiction **** 2023 **** 2022 ****
France N/A 33.0 %
Netherlands ^(1)^ N/A 33.0 %
Germany 33.0 % 33.0 %
Ireland ^(2)^ N/A N/A ​

​

^(1)^For 2023 and 2024, Netherlands has implemented a windfall royalty. This royalty applies if annual realized pricing (net of hedges) exceeds €0.50/Nm3. This royalty is assessed annually at a rate of 65% on realized pricing (net of hedges) less €0.50/Nm3 and payments on this royalty are deductible in calculating current income taxes.

^(2)^As at December 31, 2022, Ireland has not legislated a windfall tax rate. A rate of 75% was announced in November 2022.

​

Tax legislation changes

​

On December 21, 2021, the Dutch Senate approved the 2022 Tax Plan that included an increase to the Dutch corporate tax rate from 25.0% in 2021 to 25.8% in 2022. Due to the tax regime applicable to natural gas producers in the Netherlands, the increase to the corporate tax rate is not expected to have a material impact to Vermilion taxes in the Netherlands.

​

On December 28, 2019, the French Parliament approved the Finance Bill for 2020. The Finance Bill for 2020 provides for a progressive decrease of the French corporate income tax rate for companies with sales below €250 million from 32.0% to 25.8% by 2022.

​

In 2021, 136 countries and jurisdictions, including Canada, agreed to implement the Organisation for Economic Co-operation and Development’s (OECD) Pillar Two rules, effective in 2023. The proposed Pillar Two rules are designed to ensure that large multinational enterprises pay a minimum level of tax (currently agreed upon at 15%) on the income arising in each jurisdiction where they operate. The proposed rules remain subject to approval and ratification in multiple countries and jurisdictions. We are monitoring developments relating to the Pillar Two rules and implementation to assess potential impacts on Vermilion.

Vermilion Energy Inc.  ■  Page 23  ■  2022 Management's Discussion and Analysis

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​

Tax pools

​

As at December 31, 2022, we had the following tax pools:

​

​ ​ ​ ​ ​ ​ ​ ​
(M) Oil & Gas Assets **** Tax Losses **** Other **** Total
Canada 1,778,803 ^(1)^​ 1,374,896 ^(4)^​ 27,359 ^^​ 3,181,058
United States 265,091 ^(2)^​ 208,272 ^(5)^​ 57,941 ^^​ 531,304
France 293,484 ^(2)^​ — ​ — ^^​ 293,484
Netherlands 48,138 ^(3)^​ — ​ — ^^​ 48,138
Germany 198,444 ^(3)^​ — ​ 16,513 ^^​ 214,957
Ireland — ​ 803,763 ^(4)^​ — 803,763
Australia 175,126 ^(1)^​ 15,431 ^(4)^​ — 190,557
Total 2,759,086 ​ 2,402,362 **** 101,813 **** 5,263,261

All values are in US Dollars.

​

(1) Deduction calculated using various declining balance rates.
(2) Deduction calculated using a combination of straight-line over the assets life and unit of production method.
--- ---
(3) Deduction calculated using a unit of production method.
--- ---
(4) Tax losses can be carried forward and applied at 100% against taxable income.
--- ---
(5) Tax losses of $47 million created prior to January 1, 2018 are carried forward and applied at 100% against taxable income, tax losses of $161 million created after January 1, 2018 are carried forward and applied to 80% of taxable income in each taxation year.
--- ---

​

​

Financial Position Review

​

Balance sheet strategy

​

We regularly review whether our forecast of fund flows from operations is sufficient to finance planned capital expenditures, dividends, share buy-backs, and abandonment and reclamation expenditures. To the extent that fund flows from operations forecasts are not expected to be sufficient to fulfill such expenditures, we will evaluate our ability to finance any shortfall by reducing some or all categories of expenditures, with issuances of equity, and/or with debt (including borrowing using the unutilized capacity of our existing revolving credit facility). We have a long-term goal of achieving and maintaining a ratio of net debt to four quarter trailing fund flows from operations of approximately 1.0.

​

As at December 31, 2022, we have a ratio of net debt to four quarter trailing fund flows from operations of 0.8. We will continue to monitor for changes in forecasted fund flows from operations and, as appropriate, will adjust our exploration, development capital plans (and associated production targets), and return of capital plans to target optimal debt levels.

​

Maintaining a strong balance sheet is a core principle of Vermilion and will remain a focus going forward. As debt reduction continues, we will plan to increase the amount of free cash flow that is available for the return of capital, while taking into account other capital requirements.

​

Net debt

​

Net debt is reconciled to long-term debt, as follows:

​

​ ​ ​ ​
​ As at
(M) Dec 31,2022 **** Dec 31,2021
Long-term debt 1,081,351 1,651,569
Adjusted working capital deficit (1) 265,111 9,284
Unrealized FX on swapped borrowings (1,876) (16,067)
Net debt 1,344,586 1,644,786
​ ​ ​ ​
Ratio of net debt to four quarter trailing fund flows from operations 0.8 1.8

All values are in US Dollars.

​

^(1)^ Adjusted working capital is a non-GAAP financial measure that is not standardized under IFRS and may not be comparable to similar measures disclosed by other issuers. It is defined as current assets less current liabilities, excluding current derivatives and current lease liabilities. The

Vermilion Energy Inc.  ■  Page 24  ■  2022 Management's Discussion and Analysis

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measure is used to calculate net debt, a capital measure disclosed above. Reconciliation to the primary financial statement measures can be found in the “Non-GAAP and Other Specified Financial Measures” section of this document.

​

As at December 31, 2022, net debt decreased to $1.3 billion (December 31, 2021 - $1.6 billion), primarily as a result of debt repayments of $1,121.9 million, funded by the $1,083.0 million of free cash flow generated during 2022. This was partially offset by borrowings made to fund the Leucrotta acquisition, unrealized foreign exchange losses of $50.8 million on our senior unsecured notes due to the US dollar strengthening, and working capital movements. The ratio of net debt to four quarter trailing fund flows from operations decreased to 0.8 (December 31, 2021 - 1.8) due to higher four quarter trailing fund flows from operations, driven by strong commodity prices.

​

Long-term debt

​

The balances recognized on our balance sheet are as follows:

​

​ ​ ​ ​ ​
​ ​ As at
​ **** Dec 31,2022 **** Dec 31,2021
Revolving credit facility **** 147,666 1,273,755
2025 senior unsecured notes **** 404,463 377,814
2030 senior unsecured notes ​ 529,222 ​ —
Long-term debt **** 1,081,351 1,651,569

​

Revolving Credit Facility

​

As at December 31, 2022, Vermilion had in place a bank revolving credit facility maturing May 29, 2026 with terms and outstanding positions as follows:

​

​ ​ ​ ​
​ As at
(M) Dec 31,2022 **** Dec 31,2021
Total facility amount 1,600,000 2,100,000
Amount drawn (147,666) (1,273,755)
Letters of credit outstanding (13,527) (11,035)
Unutilized capacity 1,438,807 815,210

All values are in US Dollars.

​

On April 26, 2022, contemporaneous with the issuance of the 2030 senior unsecured notes and at Vermilion's election, the maturity date of the facility was extended to May 29, 2026 (previously May 31, 2024) and the total facility amount was reduced to $1.6 billion (previously $2.1 billion).

​

As at December 31, 2022, the revolving credit facility was subject to the following financial covenants:

​

​ ​ ​ ​ ​ ​ ​
​ ​ ​ ​ As at
Financial covenant **** Limit **** Dec 31,2022 **** Dec 31,2021
Consolidated total debt to consolidated EBITDA Less than 4.0 **** 0.51 1.61
Consolidated total senior debt to consolidated EBITDA Less than 3.5 **** 0.07 1.24
Consolidated EBITDA to consolidated interest expense Greater than 2.5 **** 27.10 14.78

​

Our financial covenants include financial measures defined within our revolving credit facility agreement that are not defined under IFRS. These financial measures are defined by our revolving credit facility agreement as follows:

● Consolidated total debt: Includes all amounts classified as “Long-term debt”, “Current portion of long-term debt”, and “Lease obligations” (including the current portion included within "Accounts payable and accrued liabilities" but excluding operating leases as defined under IAS 17) on our consolidated balance sheet.
● Consolidated total senior debt: Consolidated total debt excluding unsecured and subordinated debt.
--- ---
● Consolidated EBITDA: Consolidated net earnings before interest, income taxes, depreciation, accretion and certain other non-cash items, adjusted for the impact of the acquisition of a material subsidiary.
--- ---
● Total interest expense: Includes all amounts classified as "Interest expense", but excludes interest on operating leases as defined under IAS 17.
--- ---

​

In addition, our revolving credit facility has provisions relating to our liability management ratings in Alberta and Saskatchewan whereby if our security adjusted liability management ratings fall below specified limits in a province, a portion of the asset retirement obligations are included in the definitions of consolidated total debt and consolidated total senior debt. An event of default occurs if our security adjusted liability management ratings breach additional lower limits for a period greater than 90 days. As of December 31, 2022, Vermilion's liability management ratings were higher than the

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specified levels, and as such, no amounts relating to asset retirement obligations were included in the calculation of consolidated total debt and consolidated total senior debt.

​

As at December 31, 2022 and December 31, 2021, Vermilion was in compliance with the above covenants.

​

2025 senior unsecured notes

On March 13, 2017, Vermilion issued US $300.0 million of senior unsecured notes at par. The notes bear interest at a rate of 5.625% per annum, paid semi-annually on March 15 and September 15, and mature on March 15, 2025. As direct senior unsecured obligations of Vermilion, the notes rank equally in right of payment with existing and future senior indebtedness of the Company.

​

The senior unsecured notes were recognized at amortized cost and include the transaction costs directly related to the issuance.

​

Vermilion may redeem some or all of the senior unsecured notes at the redemption prices set forth in the following table plus any accrued and unpaid interest, if redeemed during the twelve-month period beginning on March 15 of each of the years indicated below:

​

​ ​ ​ ​
Year **** Redemption price ****
2022 101.406 %
2023 and thereafter 100.000 %

​

2030 senior unsecured notes

On April 26, 2022, Vermilion closed a private offering of US $400.0 million 8-year senior unsecured notes. The notes were priced at 99.241% of par, mature on May 1, 2030, and bear interest at a rate of 6.875% per annum. Interest is paid semi-annually on May 1 and November 1, commencing on November 1, 2022. The notes are senior unsecured obligations of Vermilion and rank equally with existing and future senior unsecured indebtedness.

​

The senior unsecured notes were recognized at amortized cost and include the transaction costs directly related to the issuance.

​

Vermilion may, at its option, redeem the notes prior to maturity as follows:

● On or after May 1, 2025, Vermilion may redeem some or all of the senior unsecured notes at the redemption prices set forth below, together with accrued and unpaid interest.
● Prior to May 1, 2025, Vermilion may redeem up to 35% of the original principal amount of the notes with an amount of cash not greater than the net cash proceeds of certain equity offerings at a redemption price of 106.875% of the principal amount of the notes, together with accrued and unpaid interest.
--- ---
● Prior to May 1, 2025, Vermilion may also redeem some or all of the notes at a price equal to 100% of the principal amount of the notes, plus a “make-whole premium,” together with applicable premium, accrued and unpaid interest.
--- ---

​

​ ​ ​ ​
Year **** Redemption price ****
2025 103.438 %
2026 102.292 %
2027 101.146 %
2028 and thereafter 100.000 %

​

Shareholders' capital

​

The following table outlines our dividend payment history:

​

​ ​ ​ ​ ​ ​
Date **** Frequency **** Dividend per unit or share
January 2003 to December 2007 ​ Monthly ​ $ 0.170
January 2008 to December 2012 ​ Monthly ​ $ 0.190
January 2013 to December 2013 ​ Monthly ​ $ 0.200
January 2014 to March 2018 ​ Monthly ​ $ 0.215
April 2018 to February 2020 ​ Monthly ​ $ 0.230
March 2020 ​ Monthly ​ $ 0.115
April 2022 to July 2022 ​ Quarterly ​ $ 0.060
August 2022 onwards ​ Quarterly ​ $ 0.080

​

Vermilion Energy Inc.  ■  Page 26  ■  2022 Management's Discussion and Analysis

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In the first quarter of 2022, we announced our plan to distribute a fixed quarterly dividend due to stronger commodity prices and a strengthened balance sheet. In August 2022, we announced a 33% increase to our quarterly cash dividend effective for the Q3 2022 distribution. In January 2023, we announced our plan to increase the quarterly dividend by 25% to $0.10 per share effective for the planned Q1 2023 distribution.

​

The following table reconciles the change in shareholders’ capital:

​

​ ​ ​ ​ ​
Shareholders’ Capital **** Shares ('000s) **** Amount
Balance at January 1 **** 162,261 **** 4,241,773
Vesting of equity based awards **** 2,578 **** 44,811
Shares issued for equity based compensation **** 549 **** 13,699
Share-settled dividends on vested equity based awards ​ 178 ​ 4,377
Repurchase of shares **** (2,339) **** (60,866)
Balance at December 31 **** 163,227 4,243,794

​

As at December 31, 2022, there were approximately 5.5 million equity based compensation awards outstanding. As at March 8, 2023, there were approximately 162.1 million common shares issued and outstanding.

​

On July 4, 2022, the Toronto Stock Exchange approved our notice of intention to commence a normal course issuer bid ("the NCIB"). The NCIB allows Vermilion to purchase up to 16,076,666 common shares representing approximately 10% of its public float as at June 22, 2022 beginning

July 6, 2022 and ending July 5, 2023.

​

In 2022, Vermilion purchased and cancelled 2.34 million common shares under the NCIB for total consideration of $71.7 million. Subsequent to year end 2022 and as at March 8, 2023, Vermilion purchased and cancelled 1.14 million common shares under the NCIB for total consideration of $22.4 million.

​

​

Contractual Obligations and Commitments

​

As at December 31, 2022, we had the following contractual obligations and commitments:

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​
(M) Less than 1 year **** 1 - 3 years **** 3 - 5 years **** After 5 years **** Total
Long-term debt (1) 69,235 533,362 225,861 634,875 1,463,333
Lease obligations 46,245 49,730 29,062 8,597 133,634
Processing and transportation agreements 40,267 52,786 23,133 101,629 217,815
Purchase obligations 27,481 4,907 444 285 33,117
Drilling and service agreements 5,051 58,122 — — 63,173
Total contractual obligations and commitments 188,279 698,907 278,500 745,386 1,911,072

All values are in US Dollars.

​

^(1)^ Interest on revolving credit facility calculated assuming an annual interest rate of 6.19%.
^(2)^ Commitments denominated in foreign currencies have been translated using the related spot rates on December 31, 2022.
--- ---

​

​

Asset Retirement Obligations

​

As at December 31, 2022, asset retirement obligations were $1,087.8 million compared to $1,000.6 million as at December 31, 2021. The increase in asset retirement obligations is primarily attributable to increases in inflationary market pressures and increases in estimated abandonment costs in Netherlands, France and Canada. This increase was partially offset by higher country specific risk-free rates.

​

The present value of the obligation is calculated using a credit-adjusted risk-free rate, calculated using a credit spread added to risk-free rates based on long-term, risk-free government bonds. Vermilion's credit spread is determined using the Company's expected cost of borrowing at the end of the reporting period.

​

Vermilion Energy Inc.  ■  Page 27  ■  2022 Management's Discussion and Analysis

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The risk-free rates and credit spread used as inputs to discount the obligations were as follows:

​

​ ​ ​ ​ ​ ​ ​ ​
​ **** Dec 31,2022 **** Dec 31,2021 **** Change ****
Credit spread added to below noted risk-free rates 4.5 % 4.9 % (0.4) %
Country specific risk-free rate **** ​ ​ ​ ​ ​ ​
Canada **** 3.3 % 1.8 % 1.5 %
United States **** 4.1 % 1.9 % 2.2 %
France **** 3.4 % 0.8 % 2.6 %
Netherlands **** 2.7 % (0.3) % 3.0 %
Germany **** 2.5 % 0.1 % 2.4 %
Ireland **** 3.2 % 0.5 % 2.7 %
Australia **** 4.2 % 1.9 % 2.3 %

​

Current cost estimates are inflated to the estimated time of abandonment using inflation rates of between 1.6% and 4.2% (as at December 31, 2021 - between 1.1% and 3.1%).

​

​

Risks and Uncertainties

​

Crude oil and natural gas exploration, production, acquisition and marketing operations involve a number of risks and uncertainties that have affected the financial statements and are reasonably likely to affect them in the future. These risks and uncertainties are discussed further below.

​

Commodity prices

Crude oil and natural gas prices have fluctuated significantly in recent years due to supply and demand factors. Changes in crude oil and natural gas prices affect the level of revenue we generate, the amount of proceeds we receive and payments we make on our commodity derivative instruments, and the level of taxes that we pay. In addition, lower crude oil and natural gas prices would reduce the recoverable amount of our capital assets and could result in impairments or impairment reversals.

​

Exchange rates

Exchange rate changes impact the Canadian dollar equivalent revenue and costs that we recognize. The majority of our crude oil and condensate revenue stream is priced in US dollars and as such an increase in the strength of the Canadian dollar relative to the US dollar would result in the receipt of fewer Canadian dollars for our revenue. We also incur expenses and capital costs in US dollars, Euros and Australian dollars and thus a decrease in strength of the Canadian dollar relative to those currencies may result in the payment of more Canadian dollars for our expenditures.

​

In addition, exchange rate changes impact the Canadian equivalent carrying balances for our assets and liabilities. For foreign currency denominated monetary assets (such as cash and cash equivalents, long-term debt, and intercompany loans), the impact of changes in exchange rates is recorded in net earnings as a foreign exchange gain or loss.

​

Production and sales volumes

Our production and sales volumes affect the level of revenue we generate and correspondingly the royalties and taxes that we pay. In addition, significant declines in production or sales volumes due to unforeseen circumstances may also result in an indicator of impairment and potential impairment charges.

​

Interest rates

Changes in interest rates impact the amount of interest expense we pay on our variable rate debt and also our ability to obtain fixed rate financing in the future.

​

Tax and royalty rates

Changes in tax and royalty rates in the jurisdictions that we operate in would impact the amount of current taxes and royalties that we pay. In addition, changes to substantively enacted tax rates would impact the carrying balance of deferred tax assets and liabilities, potentially resulting in a deferred tax recovery or incremental deferred tax expense.

​

Windfall taxes and royalties

Vermilion is exposed to increased taxation and royalties due to windfall taxes on profits. Windfall taxes have been substantively enacted within the European Union for oil and gas companies for 2022 and/or 2023 at a minimum rate of 33% calculated on taxable profits above a 20% increase in the average yearly taxable profits as compared to 2018 to 2021. Windfall tax rates have been legislated or, in the case of Ireland, announced as described in the preceding section “Taxes”. There remains uncertainty on whether the announced windfall tax rate in Ireland of 75% will change upon legislation.

Vermilion Energy Inc.  ■  Page 28  ■  2022 Management's Discussion and Analysis

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In addition, there is uncertainty on whether windfall taxes will continue beyond 2023 or whether similar legislation could be enacted in other jurisdictions that Vermilion operates in.

​

Ukraine War

During 2022, Russian military forces invaded Ukraine resulting in a war between the two countries. The ongoing conflict between countries has impacted the supply of oil and gas from the region and has resulted in countries throughout the world imposing financial and trade sanctions against Russia which have had macroeconomic effects. The risks disclosed in our Annual Information Form for the year ended December 31, 2022 may be exacerbated as a result of the Ukraine war, including: market risks including volatility of oil and gas prices, volatility of foreign exchange rates, volatility of market price of common shares, hedging arrangements; regulatory and political risks including tax, royalty, and other government legislation; financing risks including additional financing, debt service, variations in interest rates and foreign exchange rates; acquisition and expansion risks including international operations and future geographical/industry expansion, acquisition assumptions, failure to realize anticipated benefits of prior acquisitions.

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COVID-19

The extent of the risks surrounding the severity and timing of the COVID-19 pandemic is continually evolving; therefore, there is significant risk and uncertainty which may have a material and adverse effect on our operations. The following risks disclosed in our Annual Information Form for the year ended December 31, 2022 may be exacerbated as a result of the continued COVID-19 pandemic: market risks related to the volatility of oil and gas prices, volatility of foreign exchange rates, volatility of the market price of common shares, and hedging arrangements; operational risks related to increasing operating costs or declines in production levels, operator performance and payment delays, and government regulations; financing risks related to the ability to obtain additional financing, ability to service debt, and variations in interest rates and foreign exchanges rates; and other risks related to cyber-security as parts of our workforce continue to work through remote connections, accounting adjustments, effectiveness of internal controls, and reliance on key personnel, management, and labour.

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In addition to the above, we are exposed to risk factors that impact our company and business. For further information on these risk factors, please refer to our Annual Information Form, available on SEDAR at www.sedar.com or on our website at www.vermilionenergy.com.

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There has been no change in Vermilion’s internal control over financial reporting during the period covered by this MD&A that materially affected, or is reasonably likely to materially affect, its internal control over financial reporting.

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Financial Risk Management

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To mitigate the risks affecting our business whenever possible, we seek to hire personnel with experience in specific areas. In addition, we provide continued training and development to staff to further develop their skills. When appropriate, we use third party consultants with relevant experience to augment our internal capabilities with respect to certain risks.

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We consider our commodity price risk management program as a form of insurance that protects our cash flow and rate of return. The primary objective of the risk management program is to support our return of capital and internal capital development programs. The level of commodity price risk management that occurs is dependent on the amount of debt that is carried. When debt levels are higher, we will be more active in protecting our cash flow stream through our commodity price risk management strategy.

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When executing our commodity price risk management programs, we use derivative financial instruments encompassing over-the-counter financial structures as well as fixed and collar structures to economically hedge a part of our physical crude oil and natural gas production. We have strict controls and guidelines in relation to these activities and contract principally with counterparties that have investment grade credit ratings.

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Critical Accounting Estimates

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The preparation of financial statements in accordance with IFRS requires us to make estimates. Critical accounting estimates are those accounting estimates that require us to make assumptions about matters that are highly uncertain at the time the estimate is made and a different estimate could have been made in the current period or the estimate could change period-to-period.

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The carrying amount of asset retirement obligations

The carrying amount of asset retirement obligations ($1,087.8 million as at December 31, 2022) is the present value of estimated future costs, discounted from the estimated abandonment date using a credit-adjusted risk-free rate. Estimated future costs are based on our assessment of regulatory requirements and the present condition of our assets. The estimated abandonment date is based on the reserve life of the associated assets. The credit-adjusted risk-free rate is based on prevailing interest rates for the appropriate term, risk-free government bonds adjusted for our estimated credit spread (determined by reference to the trading prices for debt issued by similarly rated independent oil and gas producers). Changes

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in these estimates would result in a change in the carrying amount of asset retirement obligations and capital assets and, to a significantly lesser degree, future accretion and depletion expense.

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The estimated abandonment date may change from period to period as the estimated abandonment date changes in response to new information, such as changes in reserve life assumptions or regulations. A one year increase or decrease in the estimated abandonment date would decrease or increase asset retirement obligations (with an offsetting increase to capital assets) by approximately $54.0 million.

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The estimated credit-adjusted risk-free rate may change from period to period in response to market conditions in Canada and the international jurisdictions that we operate in. A 0.5% increase or decrease in the credit-adjusted risk-free rate would decrease or increase asset retirement obligations by approximately $64.8 million.

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The fair value of capital assets acquired in business combinations

In preparing the purchase price allocation for the business combinations completed in 2022, we estimate the fair value of assets acquired. Assets acquired in an acquisition primarily relates to the crude oil and natural gas reserves. The estimated fair value of the crude oil and natural gas reserves acquired is based on the present value of proved plus probable reserves and forecast commodity prices. Changes in these assumptions, including the discount rate used, would change the amount of capital assets recognized and as a result may cause rise to goodwill or gains recognized on the acquisition and future depletion and depreciation expense.

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The recognition of deferred tax assets

The extent to which deferred tax assets are recognized are based on estimates of future profitability. These estimates are based on estimated future commodity prices and estimates of reserves. As at December 31, 2022, the deferred tax asset balance of $125.5 million relates to Ireland.

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In Ireland, we are projected to use all tax pools based on forecasted reserves and pricing and have not recognized any contra valuation allowances against deferred tax assets. A 10% decrease in pricing or volumes would continue to result in no contra valuation allowance being recognized.

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Depletion and depreciation

Capital assets are grouped into depletion units, which are groups of assets within a specific production area that have similar economic lives. Depletion units represent the lowest level of disaggregation for which costs are accumulated for the purposes of calculating depletion and depreciation.

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The net carrying value of each depletion unit is depleted using the unit of production method by reference to the ratio of production in the period to the total proved and probable reserves, taking into account the future development costs necessary to bring the applicable reserves into production.

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Key judgments that are made to reserve estimates such as revisions in reserves, changes in forecast commodity prices, foreign exchange rates, capital or operating costs would impact the amount of depletion and depreciation recorded in a period.

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The estimated recoverable amount of cash generating units

Each reporting period, we assess our CGUs for indicators of impairment or impairment reversal. If an indicator of impairment or impairment reversal is identified, we estimate the recoverable amount of the CGU. Judgment is required when determining whether indicators of impairment or impairment reversal exist, as well as judgments made when determining the recoverable amount of a CGU. Changes in any of the key judgments, such as a revision in reserves, changes in forecast commodity prices, foreign exchange rates, capital or operating costs would impact the estimated recoverable amount.

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In the first quarter of 2022, indicators of impairment reversal were present in our Canada - Saskatchewan and France - Neocomian CGUs due to an increase in forecast oil prices. As a result of the indicators of impairment reversal, the Company performed impairment reversal calculations on the identified CGUs and the recoverable amounts were determined using fair value less costs to sell, which considered future after-tax cash flows from proved plus probable reserves and an after-tax discount rate of 12.0%. Based on the results of the impairment reversal calculations completed, recoverable amounts were determined to be greater than the carrying values of the CGUs tested and $144.4 million (net of $47.7 million deferred income tax expense) of impairment reversal was recorded. A 1% increase in the assumed after-tax discount rate would reduce the estimated recoverable amount of assets tested and result in a lower impairment reversal of $123.0 million while a 5% decrease in revenues (due to a decrease in commodity price forecasts or reserve estimates) would reduce the estimated recoverable amount of assets tested and result in lower impairment reversal of $220.4 million.

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In the fourth quarter of 2021, indicators of impairment reversal were present in our France - Neocomian CGU due to increases and stabilization of commodity prices resulting in increased cash flow estimates. As a result of the indicators of impairment reversal, the Company performed impairment reversal calculations on the identified CGU and the recoverable amounts were determined using fair value less costs to sell, which considered future after-tax cash flows from proved plus probable reserves and an after-tax discount rate of 12.0%. Based on the results of the impairment reversal calculations completed, recoverable amounts were determined to be greater than the carrying values of the CGU tested and $17.7 million (net of $6.2

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million deferred income tax expense) of impairment reversal was recorded. A 1% increase in the assumed after-tax discount rate would reduce the estimated recoverable amount of assets tested and result in a lower impairment reversal of $6.4 million while a 5% decrease in revenues (due to a decrease in commodity price forecasts or reserve estimates) would reduce the estimated recoverable amount of assets tested and result in lower impairment reversal of $12.9 million.

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In the third quarter of 2021, indicators of impairment reversal were present in our Ireland CGU due to an increase and stabilization in forecast gas prices. As a result of the indicators of impairment reversal, the Company performed impairment reversal calculations on the Ireland CGU and the recoverable amount was determined using fair value less costs to sell, which considered future after-tax cash flows from proved plus probable reserves and an after-tax discount rate of 12.0%. Based on the results of the impairment reversal calculations completed, the recoverable amount was determined to be greater than the carrying value and $16.7 million (net of $5.5 million deferred income tax expense) of impairment reversal was recorded. A 1% increase in the assumed after-tax discount rate would reduce the estimated recoverable amount of assets tested and result in an impairment of $5.6 million while a 5% decrease in revenues (due to a decrease in commodity price forecasts or reserve estimates) would reduce the estimated recoverable amount of assets tested and result in an impairment of $24.8 million. A 1% increase in the assumed after-tax discount rate or a 5% decrease in revenues (due to a decrease in commodity price forecasts or reserve estimates) would not affect the amount of impairment reversal recorded.

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In the second quarter of 2021, indicators of impairment reversal were present in our Alberta, Saskatchewan, Germany, Ireland and United States CGUs due to an increase and stabilization in forecast oil and gas prices. As a result of the indicators of impairment reversal, the Company performed impairment reversal calculations on the identified CGUs and the recoverable amounts were determined using fair value less costs to sell, which considered future after-tax cash flows from proved plus probable reserves and an after-tax discount rate of 12.0%. Based on the results of the impairment reversal calculations completed, recoverable amounts were determined to be greater than the carrying values of the CGUs tested and $460.4 million (net of $133.2 million deferred income tax expense) of impairment reversal was recorded. A 1% increase in the assumed after-tax discount rate would reduce the estimated recoverable amount of assets tested and result in a lower impairment reversal of $116.8 million while a 5% decrease in revenues (due to a decrease in commodity price forecasts or reserve estimates) would reduce the estimated recoverable amount of assets tested and result in lower impairment reversal of $254.9 million.

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In the first quarter of 2021, indicators of impairment reversal were present in our Australia, Alberta, Saskatchewan, and United States CGUs due to an increase and stabilization in forecast crude oil prices versus 2020 when impairment charges were taken. As a result of the indicators of impairment reversal, the Company performed impairment reversal tests on the identified CGUs and the recoverable amounts were determined using fair value less costs to sell, which considered future after-tax cash flows from proved plus probable reserves and an after-tax discount rate of 12.0%. Based on the results of the impairment reversal calculations completed, recoverable amounts were determined to be greater than the carrying values of the CGUs tested and $492.2 million (net of $170.7 million deferred income tax expense) of impairment reversal was recorded. A 1% increase in the assumed after-tax discount rate would reduce the estimated recoverable amount of assets tested and result in a lower impairment reversal of $146.4 million while a 5% decrease in revenues (due to a decrease in commodity price forecasts or reserve estimates) would reduce the estimated recoverable amount of assets tested and result in lower impairment reversal of $285.6 million.

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Off Balance Sheet Arrangements

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We have not entered into any guarantee or off balance sheet arrangements that would materially impact our financial position or results of operations.

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Cybersecurity

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Vermilion has an information security training and compliance program that is completed at least annually. We have not experienced a cybersecurity breach in the last three years.

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Recently Adopted Accounting Pronouncements

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Vermilion did not adopt any new accounting pronouncements as at December 31, 2022.

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Health, Safety and Environment

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We are committed to ensuring we conduct our activities in a manner that protects the health and safety of our employees, our contractors and the public. Our HSE Vision is to consistently apply our core values of Excellence, Trust, Respect and Responsibility. Our goal is to create a workplace free of incidents by ensuring our proactive culture and behaviours create a high-reliability organization where HSE is fully integrated into our business – it is our way of life. Our mantra is HSE: Everyone. Everywhere. Everyday.

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Vermilion seeks to maintain health, safety and environmental practices and procedures that comply with or exceed regulatory requirements and industry standards. All of our personnel are expected to work safely and in accordance with established regulations and procedures, and we seek to reduce impacts to land, water and air. During 2022 we:

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● Maintained clear priorities around 5 key focus areas of HSE Culture, Communication and Knowledge Management, Management Systems, Environmental & Operational Stewardship, and Health;
● Completed ongoing HSE performance monitoring through key performance indicator development, analysis and reporting;
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● Continued comprehensive investigations of our incidents and near misses to ensure root causes were identified and corrective actions effectively implemented;
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● Worked towards fulfilling our updated HSE Strategy and further enhanced our Visible Active Leadership program;
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● Completed a comprehensive HSE Management System Assessment across the organization;
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● Completed a gap assessment and action plan as part of our Process Safety Management System implementation;
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● Completed our 4^th^ HSE Perception Survey, analyzed the results and developed action plans;
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● Continued reinforcement of the “Vermilion High 5”, an individual safety awareness initiative aimed at keeping front-line workers safe;
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● Advanced our Energy Safety Canada and International Oil and Gas Producers Life-Saving Rules implementation and competency development;
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● Submitted our CDP Water and Climate reports;
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● Managed our waste products by reducing, recycling and recovering;
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● Reduced long-term environmental liabilities through decommissioning, abandoning and reclaiming well leases and facilities;
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● Continued the development of a robust hazard identification and risk mitigation program specific to environmentally sensitive areas;
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● Performed auditing, management inspections and workforce observations to measure compliance and identify potential hazards and apply risk reduction measures; and
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● Assessed the effectiveness of our performance management standards across multiple business units.
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We are a member of several organizations concerned with environment, health and safety, including numerous regional co-operatives and synergy groups. In the area of stakeholder relations, we work to build long-term relationships with environmental stakeholders and communities.

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Task Force on Climate-related Financial Disclosure (TCFD)

Environmental, Social and Governance (ESG)

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As an international company, Vermilion responsibly produces essential energy while delivering long-term value to our stakeholders. We believe that integrating sustainability principles into our business increases shareholder returns, enhances development opportunities, reduces long-term risks, and supports the well-being of key stakeholders including the communities in which we operate.

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Vermilion has established a leadership position in sustainability performance and disclosure, launching our first CDP Climate submission and Sustainability Report in 2014, with data to 2012, aligned with the Global Reporting Initiative (GRI). We have since adopted recommendations from the Task Force on Climate-related Financial Disclosure (TCFD), the Sustainability Accounting Standards Board (SASB), and the International Sustainability Standards Board (ISSB).

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In particular, we have applied the TCFD framework in the management of climate- and other sustainability-related risks and opportunities. This recognizes the importance of climate-specific disclosure while reflecting its intersection with other environment-related risks and opportunities, social factors such as safety and community engagement, and governance issues. Our Index follows:

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●<br><br>Governance Information Circular
●<br><br>Strategy Annual Report MD&A
●<br><br>Risk Management Annual Report MD&A
●<br><br>Metrics and Targets Annual Report MD&A
●<br><br>Consolidated Climate (TCFD) Report www.vermilionenergy.com/sustainability/reports/

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Sustainability and Climate-Related Strategy

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Vermilion understands our stakeholders’ expectations that we deliver strong financial results in a responsible and ethical way. As a result, we align our strategic priorities in the following order:

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● the safety and health of our staff and those involved directly or indirectly in our operations;

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● our responsibility to protect the environment. We follow the Precautionary Principle introduced in 1992 by the United Nations "Rio Declaration on Environment and Development" by using environmental risk as part of our development decision criteria, and by continually seeking improved environmental performance in our operations; and
● economic success through a focus on operational excellence across our business, which includes technical and process excellence, efficiency, expertise, stakeholder relations, and respectful and fair treatment of staff, contractors, partners and suppliers.
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Reflecting these priorities, we have positioned Vermilion purposefully within the energy transition. Our scenario analysis has consistently demonstrated that Vermilion can best contribute by focusing on producing energy responsibly: safely, reliably and cost-effectively. Our Sustainability Report provides further details at: www.vermilionenergy.com/sustainability.

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Description of Sustainability- and Climate-related Risks and Opportunities, and Impacts

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Given the intersection of environmental and social issues, and their impact over varying timeframes, we have identified climate-related risks and opportunities within short-term (0-3 years), medium-term (3-6 years) and long-term (6-50 years) horizons. We describe these below, along with their potential company and financial impact (assessed using processes such as scenario analysis, cost projections and our Emissions Long-Range Planning tool), and our resulting management approach, including operations such as equipment upgrade, and capital allocation. Our annual CDP Climate Change and Water Security submissions provide additional information, including where in the value chain these risks and opportunities occur: see www.vermilionenergy.com/sustainability/reports/.

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Category / <br>Issue Description of Impacts Potential Financial Impact Management Approach
Short-term Transition Risks (0-3 Years)
Policy and Legal:<br><br>Increased Pricing of GHG Emissions<br><br>e.g. Carbon Tax Short-term impact is primarily in Canada and Ireland. Canadian Federal Greenhouse Gas Pollution Pricing Act has set carbon tax rates at $50 per tCO2e in 2022, rising to $170 by 2030. Our exposure is mitigated by provincial responses to the Act, including Alberta's Technology Innovation and Emissions Reduction (TIER) regulation and Saskatchewan’s Output-Based Pricing System (OBPS). Our Ireland operations are subject to the EU ETS and Ireland Carbon Tax systems.<br><br>Longer-term impact rests on carbon pricing’s vulnerability to changes in government policy. We note the political focus in the EU, Canada and USA on a COVID-19 economic recovery that is both climate-focused and responsive to social justice issues such as labour practices. With our recent Montney acquisition, our Canadian carbon tax liability increased to approximately $0.7MM in 2022, and is forecasted to exceed $1MM/year in the near term. Our Ireland EU ETS liability is forecast to be approximately $0.8MM in 2022, increasing to approximately $2.6MM in 2025 and $3.5MM in 2030. The Ireland Carbon Tax liability is expected to be an additional approximately $0.1MM/year over this period. All of the liability estimates are net Vermilion. We voluntarily opted into Alberta’s TIER regulation, which provides tax exemptions contingent on emissions reduction activities that Vermilion is in the process of implementing. Our ongoing efforts to reduce the energy and emissions intensity of our operations are integral to managing this risk, including our announcement of two emission reduction targets in 2021. Vermilion continues to monitor and comply with taxation requirements, engaging external subject matter experts and in-house experts in engineering, asset integrity, optimization, health safety & environment, and sustainability that assess our operations.
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Policy and Legal:<br><br>Enhanced Emissions & Other ESG Reporting Obligations Climate and other ESG reporting obligations are evolving rapidly, with Vermilion potentially subject to European Sustainability Reporting Standards, U.S. Securities and Exchange Commission Climate-Related Disclosure Rules, and Canadian Securities Administrators Climate-Related Disclosure Rule, much of which is founded on the work of TCFD, SASB and the International Sustainability Standards Board. Although Vermilion's existing sustainability-related disclosure provides a sound foundation for compliance with these proposed rules, there are costs to monitor developments and respond to the final versions, particularly potential requirements for increased levels of audit. The impact to Vermilion would be a decreased netback per BOE, due to increased expenses for staff time and system development and implementation. The financial impact is an increase in operational cost associated with the management and quantification of emissions to meet new reporting requirements, and the administrative costs associated with reporting and audit obligations. This is built into Vermilion's budgeting and is currently estimated at $0.5MM annually. Regulations in all of our business units are monitored on an ongoing basis, and assumptions/scenario planning is used annually to assess risk. In Canada, we implemented an external emission data gathering software in 2021 to support the evolving regulatory landscape. Vermilion also engages stakeholders relating to emissions reporting obligations. Management of this risk is built into Vermilion's operations and our ERM. In addition, we expect to automate our emissions data gathering, aggregation and calculation processes in 2023-2024, while ensuring audit-ready processes for all ESG data points to align with proposed regulatory requirements.
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Category / <br>Issue Description of Impacts Potential Financial Impact Management Approach
Policy and Legal and Technology:<br><br>Mandates on and Regulation of Existing Products and Service, and Changes in Emissions Regulations; and Market and Reputational: Changing Customer Behaviour Vermilion's operations are subject to regional regulatory changes that result in changes to equipment requirements such as engineering and equipment modifications to reduce carbon emissions and / or emissions of criteria air contaminants. The most likely short-term impact is regulations in Canada to reduce methane emissions, in France to reduce flaring and in Netherlands to reduce NOx.<br><br>​<br><br>From a macro perspective, geopolitical impacts (e.g. war in Ukraine) have escalated diverging government and consumer viewpoints on the need for energy security vs energy transition. We expect that demand for oil and natural gas to remain strong in the short term, while safety and environmental regulations governing its production will increase.<br><br>​<br><br>We have identified these risks as interconnected and existing in the short-term; however, they should be seen as medium- to long-term risks as well. Operational changes to comply with existing methane reduction regulations is expected at approx. $1.5MM in the short term, with those associated with eliminating routine flaring in France subject to continuing review in 2023.<br><br>​<br><br>The cost of compliance with proposed regulations, such as Canada's proposed regulatory framework for reducing oil and gas methane emissions to achieve a 75% reduction by 2030 is not yet established, and will depend on the final version of the framework. Vermilion is closely monitoring regulatory and market changes to ensure its approach to resilience under evolving conditions remains appropriate. We provide feedback to governments on proposed regulations, as per our lobbying disclosures, and allocate resources, including staff and capital, to ensure that required operational changes can be effectively actioned. In the short term, tying in vented equipment to flaring infrastructure in Canada is an example of projects to address this risk; in Netherlands we have used NOx scrubbers and purchased NOx certificates to comply with new regulations.<br><br>​<br><br>Our ongoing efforts to proactively reduce the energy and emissions intensity of our operations are integral to managing this risk, including our announcement of two emission reduction targets in 2021, and our work in 2022-2023 to establish a clear net zero to 2050 plan and 2030 emissions reduction target. We are also working with external partners to further implement and develop emission reduction technologies that are economic to the Company, in part due to the potential generation of carbon credits.<br><br>​<br><br>Based on stakeholder engagement, Vermilion believes that independent assessments of our operations by third parties are an important tool to demonstrate our responsible approach to production of essential energy. As a result, we have sought and achieved Equitable Origin responsible gas producer certification for 3 of our Canadian sites, the AFNOR CSR Committed label in France, and the Business Working Responsibly mark in Ireland.
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Medium-term Physical Risks (3-6 Years)
Acute:<br><br>Increased Severity of Extreme Weather Events such as Cyclones and Floods Vermilion owns and operates an offshore platform in the Wandoo field off northwestern Australia, co-owns and operates the Corrib project off the Irish coast, and owns and operates oil fields in the coastal area of SW France. Extreme weather events have the potential to directly impact our offshore operations resulting in down time or damage to infrastructure, and can impact the downstream handling capacity of our partners, resulting in a limitation to the distribution and sale of our products. Based on the value of the Wandoo Platform and a 1-in-10,000-year cyclonic event, the financial implications associated with damage due to a severe weather event is estimated at $274MM (total impact before insurance). The third-party costs associated with potential damages from extreme weather events are not tracked. Vermilion maintains insurance as a mitigative measure to reduce the financial impact associated with damage to our assets due to severe weather events. We also have a robust asset integrity program that maintains our offshore facilities to their original design specifications of CAT 5 hurricane force. We also have protocols for monitoring and preparing for cyclones, and have invested in our emergency response capabilities in the event of damage to our assets due to severe weather.
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Category / <br>Issue Description of Impacts Potential Financial Impact Management Approach
Long-term Transition Risks (6-50 Years)
Technology:<br><br>Substitution of existing products and services with lower emissions options Although we see demand for oil and natural gas remaining robust in the short- to mid-term, it is likely that demand for oil and, to a lesser degree, natural gas will eventually fall as the energy transition evolves and various alternatives for renewable energy options become technologically and economically available. This could impact the need for our products in the longer term, post 2030 for oil and even further out for natural gas. As 2021 and 2022 have demonstrated, it will be critical to maintain adequate supplies of both oil and natural gas during the energy transition, to provide both accessibility and affordability. Given the uncertain timeline and progression of the energy transition, and supply-demand dynamics, we are not using a financial forecast for impact. We are, however, using our scenario analysis to identify potential opportunities that would mitigate the risk to our products. Based on our scenario analysis, we identified the need to explore new and evolving technologies and processes to identify synergistic fits for our business in both traditional and renewable energy production. We are pursuing this via our established track record in geothermal energy from produced water, for which our internal expertise in engineering, geoscience and drilling is particularly well suited. We are also investing in early R&D in other areas, such as biogas and the conversion of traditional oil and gas assets to geothermal and hydrogen production, to better understand the long-term potential.
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Long-term Physical Risks (6-50 Years)
Chronic:<br><br>Changes in Temperature Extremes, Including Rising Mean Temperatures A decrease or increase in the temperature extremes experienced in winter/summer months (i.e. lower seasonal lows, higher seasonal highs) could result in an increase in fuel gas for a variety of equipment essential for safe production, along with additional equipment (e.g. building heaters, line heaters). This would require additional resources (infrastructure) as well as increase our carbon footprint. Temperature extremes also have the potential to increase capital costs associated with drilling, completion and workover operations due to increased timelines, decreased productivity, equipment breakdown, etc. For example, an overall increase in seasonal lows (warmer winters) would have a direct impact on Vermilion's more northern onshore operations, via a decreased ability to access lands and an increase in construction capital requirements. The financial implications on an annual basis are difficult to quantify; however, based on Vermilion's experience, the most significant financial implications would result from shutdowns in drilling or completions locations. The estimated cost of this would be $0.5MM per day of delay. As weather extremes cannot be controlled, Vermilion uses our Management Systems and processes to protect the health and safety of our workers, contractors and the public, and to protect the environment from adverse effect. For example, we have reduced the potential impact related to access in remote assets by using multi-well pads wherever possible. This would significantly decrease capital considerations in the event that limited frost days occurred. Each risk associated with weather is assessed on a case-by-case basis.
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Chronic:<br><br>Changes In Precipitation Patterns and Extreme Variability in Weather Patterns Vermilion holds assets inland, in coastal regions, and offshore, where a change in precipitation could negatively impact on operations due to drought or flooding. Flooding could result in limited access to locations / facilities, and poses a risk to our corporate headquarters. Alternatively, drought conditions could impact the availability of surface and / or groundwater, which Vermilion, in part, relies on for drilling and completion activities. This could negatively impact forecasted growth by increasing the timelines and capital costs to bring new infrastructure onto production. The financial implications of a single time event (i.e. wildfire) have been assessed on a case-specific basis, and are believed to be substantive (impact > $10.0MM). Vermilion maintains insurance to mitigate the potential impact of precipitation-related extreme events (i.e. Wildfire, Flooding). As these incidents are out of Vermilion's control, we take all measures possible to ensure effective emergency response to extreme weather events, to ensure the protection of the health and safety of our workers, contractors and the public, the protection of the environment and limiting the financial impact of the event. In the case of a longer term extreme precipitation event or drought, Vermilion would implement water management programs to reduce our reliance on fresh water sources to limit the potential impact on operations.
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Chronic:<br><br>Rising Sea Levels Vermilion owns and operates assets in the Netherlands, where we have assessed the potential risk associated with rising sea levels. This could physically impact our operations due to issues such as flooding, transportation difficulties and supply chain interruptions. Rising sea levels also pose a threat related to the salinization of groundwater. We have estimated that a rise in sea level could have a financial impact of $571MM before insurance at our main gas processing facility Garijp (GTC) in the Netherlands, caused by an extreme 1-in-10000-years tide/extreme wind event. Other than conventional berm protection, there is no measure available to protect Vermilion's assets in the Netherlands if water levels rise to a level resulting in one of our main facilities being temporarily invaded by sea water. Based on Vermilion's assessment of the probability of these events occurring over the next 5 years being less than 0.05%, Vermilion has accepted this level of risk exposure. Vermilion currently includes a review of this risk in our annual risk management process.
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Category / <br>Issue Description of Impacts Potential Financial Impact Management Approach
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Short-term Opportunities (0-3 Years)
Products and Services, and<br><br>Resilience:<br><br>Development of New Products and Services through R&D and Innovation; participation in renewable energy programs Directly related to the long-term transitional risk associated with the substitution of low-carbon products, we have the opportunity to participate in the development of those products. This has the potential to reuse our current infrastructure to provide alternative products, such as biogas or hydrogen, or to develop new products such as geothermal energy, creating new revenue streams.<br><br>An example of this opportunity is the geothermal heat we are providing heat from the produced water in our oil operations to develop sustainable agriculture and residential projects near our operations. As this opportunity is in the early stage of assessment, it is difficult to quantify the financial impact, but it is estimated at up to $2.0MM per year in revenue and returns on investment. Potential also exists for significant cost adjustments, as assets slated for abandonment would be repurposed to enable them to continue to generate energy. We are leveraging our technical experts and partnerships to provide input into alternative and renewable energy projects as they are identified. An example of the development of low emission goods/services is our France-based industry partnership with Avenia to expand the use of geothermal energy production in oil production, and a geothermal association in Germany. We have also developed criteria for approving the move of these ideas into our Vermilion Opportunity Development Process, which provides clear gates and criteria for considering and implementing such projects.
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Products and Services:<br><br>Access to New Markets More stringent global measures to reduce emissions from individual ships by 30% by 2030, established through amendments to MARPOL Annex VI, came into force on Jan 1 2020, limiting the sulphur content of bunker fuel to a maximum of 0.5%. Vermilion’s Australian Wando facility produces 4500 bbl/d of low sulphur crude oil that meets the needs of refineries in the short term to meet IMO regulations. Vermilion conservatively foresees achieving a premium of $10/bbl for its Wandoo production over the next three years for cumulative incremental revenue of $49.3MM. Vermilion continues to access local markets for our low sulphur production, while exploring regions to expand our operations. Our Marketing group ensures that Vermilion meets its contractual obligation with our buyers in terms of volumes, delivery dates and crude quality.
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Products and Services:<br><br>Ability to Diversify Business Activities; Shift in Consumer Preferences Vermilion maintains a diverse, stable global portfolio of oil and gas assets. Our strong record of safe and socially conscious development of energy resources has provided opportunities to access and develop these resources. We see our commitment to sustainability as core to our business, which has provided important organizational focus on emissions quantification and management. As consumers become more aware of and involved in the selection of their energy sources and associated carbon intensity, we believe that Vermilion will continue to be a top quartile choice, providing us with opportunities not available to peer organizations. The financial impact of changing consumer preferences in difficult to quantify. We foresee revenue opportunities in two distinct areas. (1) In consumers selecting premium energy products, with these products demanding a higher price than other energy sources on the market; currently we estimate the potential impact of premium pricing in the long-term to be $1-5 per BOE, or $31.1MM/year based on $1 at 2022 production levels. (2) Access to more stringent markets, supported by our environmental and sustainability performance. Vermilion has entered into German, Hungarian, Croatian and Slovak oil and gas operations, which our sustainability performance has supported. Based on stakeholder engagement, Vermilion believes that independent assessments of our operations by third parties are an important tool to demonstrate our responsible approach to production of essential energy, and generate premium. As a result, we have sought and achieved Equitable Origin responsible gas producer certification for 3 of our Canadian sites, the AFNOR CSR Committed label in France, and the Business Working Responsibly mark in Ireland. We are currently assessing the potential to expand these certifications.
​
Medium-term Opportunities (3-6 Years)
Energy Source:<br><br>Participation in Carbon Market Under the revised EU ETS Directive in effect 2021-2030, it is anticipated that there will be an active market and consumers for the offset credits generated at some of Vermilion's sustainability initiatives around the world. This shift in the cap and trade scheme may provide opportunities for Vermilion to generate certified energy reduction / offset credits through our geothermal cogeneration projects in France; however, current carbon markets are experiencing significant volatility, including reputational impacts to voluntary markets. Vermilion is not accounting for any short term financial impact due to the volatility in current markets. We will continue to evaluate the benefit that certified offset credits from various emission reduction projects across our operations could provide.<br><br>​<br><br>Examples of projects that have the potential to generate credits include four geothermal co-production projects in France. Vermilion's project assessment framework is applied to each identified opportunity, including considerations associated with emissions offset.

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​

Category / <br>Issue Description of Impacts Potential Financial Impact Management Approach
Long-term Opportunities (6-50 Years)
Products and Services:<br><br>Shift in Consumer Preferences Under the Canadian Environmental Protection Act and based on commitments made by the Canadian and Alberta governments and energy utilities relating to COP21, there is a commitment to reduce emissions for coal-fired power generation. Based on this and with a number of power generating facilities in Alberta nearing the end of their service life, the demand for natural gas is likely to increase due to increased use of combined cycle gas turbine (CCGT) power generation. The short term impact of this regulatory change on gas pricing is anticipated to be low and increase to medium in the mid- to long-term. Once the regulations have come into effect and the implementation period has occurred, there is a potential to see an impact on the marketable price and demand for natural gas. As a natural gas and oil producer, Vermilion would benefit from an increase in marketable prices for natural gas in our Canadian operations. As we move further into the energy transition, we foresee natural gas playing an impactful role as a less carbon intense fuel than other options (i.e. coal). Vermilion continues to focus on the identification of resources and assets where we have the opportunity to apply our industry leading expertise to optimize production while reducing emissions. An example of our strategy to realize this opportunity is our asset base in Alberta, which currently includes a large liquids rich gas play. Vermilion's marketing team is also actively pursuing options for our natural gas production that will enable Vermilion to achieve the best netbacks on production.
​ ​ ​ ​
Energy Source:<br><br>Shift Toward Decentralized Energy Generation The carbon intensity of energy used around the world has a direct relationship to where the energy product was generated. Vermilion’s business unit structure supports production and distribution of energy products into local markets. This strategy results in the significant reduction of the carbon footprint of our energy when compared to non-local sources. The long-term financial impact of decentralized energy generation will depend on the speed of the energy transition balanced against the need for energy security. As such, we believe it is not possible to predict the financial impact at this time. Vermilion continues to assess where we can access local markets for our production, while exploring regions to expand our operations. The actions taken in the past several years to realize this opportunity include alterations to our structure, our strategic objectives and our operational development plans to support Vermilion as a distributed energy provider, and exploration and development programs in regions with relatively low energy production as compared to consumption (i.e. Hungary).

​

​

​

Resilience of the Company’s Strategy

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Countries in all of our operating regions have implemented policies to support a low-carbon future for the world’s economy, consistent with a 1.5-2C or lower scenario. As a global energy producer, we contribute to the supply of safe, reliable and affordable energy during this transition; our strategy is therefore based on our risk and opportunity identification, which in turn contributes to our materiality analysis. This analysis is based on double materiality, considering issues based on both external and internal impacts. The Board of Directors and senior leadership used these analyses in our scenario analysis. Vermilion uses two energy transition scenarios from the World Economic Forum. These compare a Gradual versus Rapid low-carbon transition based on inputs that include the International Energy Agency’s New Policies Scenario (Gradual) and Sustainable Development Scenario (Rapid), which meets the Paris Agreement’s goal to limit global temperature increases to 1.5 to 2ºC. Vermilion examines key factors impacting the speed of the transition – including the influence of new energy technologies; potential speed of their adoption; anticipated changes in policy and regulation; and emerging market pathways such as India – and resulting factors that could impact the Company, including economics (demand, supply, consumer behaviour, and costs of energy); technological advancement; capital availability; government policy; and Company reputation. Among these, government policy is seen as most influential in the near to mid-term.

​

We applied these findings to Vermilion’s strategy to 2050 and beyond, described below. In particular, the scenario analysis led us to develop two emission-related targets that were announced in 2021: an aspirational commitment to net zero emissions in our own operations, including Scope 1 and Scope 2 emissions, by 2050, and a near-term target to reduce Scope 1 emissions intensity from our operations by 15 to 20% by 2025, using a baseline year of 2019. See Metrics and Targets, below, for more information.

​

In 2022, we furthered this commitment by establishing high-level approaches to net zero, including: reducing emissions; converting production by replacing end-of-life fields with lower intensity production; adapting to new technology such as carbon capture and storage and renewable energy; and — when no other options exist — a careful approach to offsetting. We are building out this plan in 2023, including establishing our next emissions reduction target, for 2030.

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Overall, our strategy to ensure our resilience under various scenarios rests on three strategic activities:

​

● Focusing on efficient and responsible production of oil and natural gas, viewing emissions as potential energy sources:
° Lower carbon fuels. Since 2012, we have shifted our production mix towards natural gas as a cleaner burning fuel than other fossil fuels. We also sell our fuels within the country of production wherever possible, reducing the carbon footprint associated with transportation of the fuel to consumers while increasing national energy security.
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° Socially responsible fuels. We are committed to ensuring that our products are produced in an environmentally and socially responsible manner, respecting worker rights and community engagement. We operate in regions noted for their stable, well-developed fiscal and regulatory policies related to oil and gas exploration and development, and for their robust health, safety, environmental and human rights legislation.
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° Transparency and reporting. We have established a strong record of reporting on greenhouse gas emissions, energy usage and other key environmental metrics, which has supported our emission reduction targets.
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● Implementing technically and economically feasible options for emission reduction, covering combustion, flaring, venting and fugitive emissions:
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° Greater energy efficiency. Many energy and operational efficiency initiatives go hand-in-hand, which in turn helps us minimize our carbon footprint and reduce greenhouse gas emissions.
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° Lower greenhouse gas emission intensity. We are committed to reducing the greenhouse gas emissions associated with our production, with particular focus on methane.
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● Exploring new and evolving technologies and processes to identify synergistic fits for our business in both traditional and renewable energy production:
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° Alternative energy. We are continuing to develop our knowledge and use of alternative energy sources, including geothermal energy, for which our internal expertise in engineering, geoscience and drilling is particularly well suited. This work has begun with the geothermal potential of our produced water, supporting a circular economy model that conserves, reuses and recycles resources to better protect our environment. It is also expanding into areas such as biogas and the conversion of traditional oil and gas assets to geothermal and hydrogen production.
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In addition, we identified two further pillars of our sustainability strategy that are integral to managing sustainability- and climate-related issues:

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Conservation

​

We are committed to reducing the impact our operations have, beginning with regulatory compliance across all business units. Our conservation efforts are further focused in three areas:

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● Water: We recognize water as a basic human right, and as a vital resource that is shared among many stakeholders in our communities. We are therefore committed to protecting both the supply and the quality of water sources in our areas of operation by:
° Proactively preventing harm and supporting healthy surface and groundwater bodies
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° Reducing potable and freshwater usage to the lowest level practical, and
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° Taking a lifecycle and circular economy approach to water, exploring opportunities to reuse and recycle products such as produced water
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● Asset Retirement Obligations: We are adapting our long-term Asset Retirement Obligation management to include revitalizing or reusing assets to benefit our environment and our communities.
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● Biodiversity: We are focusing on protecting the species and habitats around us by proactively identifying biodiversity risks and opportunities, and implementing associated plans.
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Community

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Our communities comprise a wide diversity of people and organizations, but they have one key thing in common: they care deeply about the safety, environmental stewardship and corporate citizenship that we bring to our local operations. In addition, our people care deeply about their communities - whether we work there or live there, these are the places we call home. We therefore steward our operations and relationships to demonstrate our commitment to being a responsible producer and a valued and trusted neighbor and business partner, including:

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● Transparency with respect to safe and environmentally responsible operations, including our potential impacts on local communities
● Maintaining strong, genuine relationships with our communities, with engagement based on respect, listening and openness, and
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● Creating a shared value focused on local economic and social development
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Sustainability and Climate-Related Risk Management

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Process for Identifying, Assessing and Managing Sustainability- and Climate-related Risks, and

​

Integration into the Company’s Enterprise Risk Management (ERM) System

​

Sustainability-related risks and opportunities, including those related to climate, are integrated into multi-disciplinary Company-wide risk identification, assessment, and management processes as part of our ERM system, based on the Committee of Sponsoring Organizations of the Treadway Commission (COSO) framework. This provides an integrated approach to managing risk as it impacts strategy and performance, and includes Operational, Market & Financial, Credit, Organizational, Political, Regulatory Compliance, Strategic and Reputational, and Sustainability categories. Our sustainability materiality analysis, which assesses issues with impact for both the Company and our key stakeholders, is integrated into our ERM system using the Corporate Risk Register through a collaboration between our Finance, HSE and Sustainability teams.

​

Overall, risk management is the responsibility of the Board and the Executive Committee based on a Top-Down, Bottom-Up approach to engage all staff. Top-Down begins with our Board and its committees with clear terms of reference, including oversight for identification and management of specific allocations of risk type. This is translated into action by our Executive Committee, which reviews and manages the ERM process through implementation of associated policies and procedures. Our staff help develop systems, standards and procedures. Bottom-Up is how staff implement, maintain and improve risk management processes, applying the hazard-risk-mitigation process in every part of our business.

​

Risks are identified by key staff across our Company, including our Operations, Finance, Health, Safety and Environment, Economics, Government and Public Relations, and Sustainability teams at corporate, business unit and asset levels. These employees have significant experience, and use a wide array of inputs, including operational and facility assessments, technical and research reports, external stakeholder organizations, government policy and regulation changes, industry initiatives, communities and landowners, and non-governmental entities.

​

The results are incorporated into our Corporate Risk Register, which provides a consistent framework to ensure the effective tracking and communication of our material risks. Using our Risk Matrix as a prioritization tool, Teams assess severity, likelihood, speed of onset, and vulnerability using scales from 1 to 5 for each factor, described in terms of human, environment, financial, social license and cybersecurity impacts. Every risk case has also been assessed to determine where sustainability- or climate-related risk is a contributing factor. The results are provided annually at minimum to senior management, the Executive Committee and the Board and its Committees as appropriate, who further assess the risks including interdependencies.

​

Our risk management approach focuses on reducing the risk to a level as low as reasonably practicable, accepting the risk, and/or controlling it (such as insuring it). For example, if direct mitigation is not possible (e.g. changes in temperature extremes), we would adapt our business processes to reduce the potential impact (e.g. changing work hours to avoid extreme mid-day heat). In other situations (e.g. increasing risk of flood), we may take measures to protect against the risk (e.g. flood controls) while also insuring our operations.

​

To support climate risk identification and management, we developed a Carbon Liability Assessment Tool, with Scope 1 emissions quantification and regulatory information for each business unit. We assessed the price of carbon on both a realized cost and shadow pricing basis, and have identified likely carbon pricing scenarios for all our operating areas. The Tool provides the basis for developing carbon liability risk cases for all business units, supports ongoing identification of carbon opportunities, and supports activities such as business development, taxation review and marginal abatement cost curve preparation. In 2022, we built on this approach by developing our Emissions Long-Range Planning Tool. This is based on our long-range planning tool for production, and allows us to forecast emissions, carbon taxes and the impact of various emission reduction projects. This supports our decision-making on production, capital allocation, and mergers and acquisitions.

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Sustainability and Climate-Related Metrics and Targets

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Metrics Used to Assess Sustainability- and Climate-Related Risks and Opportunities

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Our sustainability reporting (www.vermilionenergy.com/sustainability) continues to describe significant economic, environmental, social and governance measures, which are reported with reference to TCFD, SASB and GRI. These include but are not limited to:

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● Climate: energy consumption and intensity; investment in and generation of renewable energy; greenhouse gas emission and intensity, including flaring and venting, and avoided emissions; and water withdrawal, including from areas of high baseline water stress, and discharge.
● Environment: Waste generation and management; Asset integrity and spills; and Environmental investment
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● Social: Health and Safety; People; and Community investment
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● Governance: Ethics
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These metrics contribute to our performance for CDP Climate, and S&P Global Corporate Sustainability Assessment and Sustainalytics, which comprise 10% of the Corporate Performance Scorecard for our Long-term Incentive Plan. In addition, HSE metrics comprise 25% of the scorecard for our Short-Term Incentive Plan. These plans apply to all employees, including our executive team.

​

We also track carbon pricing, and have identified actual and likely pricing scenarios for all of our operations based on current government policies and published research relating to the Paris Agreement. For example, in Canada, the 2022 carbon tax was $50 per tCO2e, and in Ireland, carbon pricing was 41 € per tCO2e. Further information is available in our CDP Climate submission, available at vermilionenergy.com/sustainability/reports/.

​

In addition, we benchmark our performance via third-party ESG rating agencies, including:

​

● CDP Climate Change and Water Security: Climate Score of A- and Water score of “B” in 2022.
● ISS ESG QualityScore: Decile rating of “1” for Environmental and Social practices as of March 2023.
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● MSCI ESG Rating: AAA in 2022.
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● S&P Global Corporate Sustainability Assessment: Top of our peer group in 2022.
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Scope 1, 2 and 3 GHG Emissions Disclosure

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We report Scopes 1, 2 and 3 emissions, which are externally verified under ISO 14064-3. Historical, corporate and business unit data can be found in the Energy and Emissions Performance Metric document available at www.vermilionenergy.com/sustainability/, summarized in the charts below. The 2018 increase in emissions was associated with the acquisition of southeast Saskatchewan assets. Our Scope 1 and 2 emissions intensity and methane emissions intensity decreased in 2019 and 2020, primarily related to our first full year of operatorship for the Corrib gas asset in Ireland, and our focus on reducing post-acquisition emissions over time through superior operations, as we did in 2014 to 2017 following the acquisition of previous Saskatchewan assets. This has been achieved through a variety of gas conservation and recovery initiatives including construction of new infrastructure, operational changes and increased infrastructure runtimes. Additional decreases have been achieved through improved measurement and methodologies, projects such as replacing diesel or propane with compressed natural gas for boilers and water heating for the drilling program in Alberta, converting pneumatic devices from high- to low-bleed, installing solar-powered chemical injection pumps, and the purchase of renewable energy certificates for electricity use in Netherlands and Ireland.

​

​ ​

​

Related Targets and Performance

​

Vermilion has committed to two emission-related targets:

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● Net zero emissions in our own operations, including Scope 1 and Scope 2 emissions, by 2050. We are transparent that this is an aspirational goal, and that we will continue building the plan to achieve this target over time.
● As a first step, we set a near-term target to reduce Scope 1 emissions intensity from our operations by 15 to 20% by 2025, using a baseline year of 2019. We will set new targets every five years at minimum, building on this foundation while exploring broader options, including the potential to reduce Scope 3 emissions.
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● In 2022, we furthered this commitment by establishing high-level approaches to net zero, including: reducing emissions; converting production by replacing end-of-life fields with lower intensity production; adapting to new technology such as carbon capture and storage and renewable energy; and — when no other options exist — a careful approach to offsetting. We continue to build out this plan in 2023, including establishing our next emissions reduction target, for 2030.
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We are tracking our performance using Scope 1 and 2 absolute and intensity emission metrics, and were on track as of end of year 2021 with a 5% decrease in Scope 1 emissions intensity. Fiscal year 2022 environmental reporting will be available in mid-2022 at https://www.vermilionenergy.com/sustainability/, where additional targets to reduce emissions and methane in our southeast Saskatchewan assets, reduce Scope 2 emissions in our Netherlands and Ireland Business Units, and generate renewable energy in our France Business Unit can also be found.

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For more information on our sustainability- and climate-related performance, please see our 2023 Proxy Statement and Information Circular, online sustainability reporting, particularly the Index and Performance Metrics sections, and 2022 CDP Responses.

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Corporate Governance

​

We are committed to a high standard of corporate governance practices, a dedication that begins at the Board level and extends throughout the Company. We believe good corporate governance is in the best interest of our shareholders, and that successful companies are those that deliver growth and a competitive return along with a commitment to the environment, to the communities where they operate, and to their employees.

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We comply with the objectives and guidelines relating to corporate governance adopted by the Canadian Securities Administrators and the Toronto Stock Exchange ("TSX"). In addition, the Board monitors and considers the implementation of corporate governance standards proposed by various regulatory and non-regulatory authorities in Canada. A discussion of corporate governance policies is included each year in our proxy materials for our annual general meeting of shareholders, copies of which are available on SEDAR (www.sedar.com).

​

As a Canadian reporting issuer with securities listed on the TSX and the New York Stock Exchange (“NYSE”), Vermilion is required to comply with all applicable Canadian requirements adopted by the Canadian Securities Administrators and the TSX, and applicable rules for foreign private issuers adopted by the U.S. Securities and Exchange Commission that give effect to the provisions of the Sarbanes-Oxley Act of 2002.

​

Our corporate governance practices also incorporate many “best practices” derived from those required to be followed by US domestic companies under the NYSE listing standards. We are required by Section 303A.11 of the NYSE Listed Company Manual to identify any significant ways in which our corporate governance practices differ from those required to be followed by US domestic companies under NYSE listing standards. We believe that there are no such significant differences in our corporate governance practices, except as follows:

​

● Shareholder Approval of Equity Compensation Plans. Section 303A.8 of the NYSE Listed Company Manual requires shareholder approval of all “equity compensation plans” and material revisions to those plans. The definition of “equity compensation plans” covers plans that provide for the delivery of newly issued securities, and also plans which rely on securities reacquired on the market by the issuing company for the purpose of redistribution to employees and directors. The TSX rules provide that equity compensation plans and material amendments thereto require shareholder approval only if they involve newly issued securities and the amendments are not otherwise addressed in the plan’s amendment procedures. In addition, the TSX rules require that every three years after institution, all unallocated options, rights or other entitlements under equity compensation plans which do not have a fixed maximum aggregate of securities issuable must be approved by shareholders. Vermilion follows the TSX rules with respect to shareholder approval of equity compensation plans and material revisions to those plans.

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Disclosure Controls and Procedures

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Our officers have established and maintained disclosure controls and procedures and evaluated the effectiveness of these controls in conjunction with our filings.

​

As of December 31, 2022, we have evaluated the effectiveness of the design and operation of our disclosure controls and procedures. Based on this evaluation, the Chief Executive Officer and the Chief Financial Officer have concluded and certified that our disclosure controls and procedures are effective.

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Internal Control Over Financial Reporting

​

A company's internal control over financial reporting is a process 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 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.

Vermilion Energy Inc.  ■  Page 42  ■  2022 Management's Discussion and Analysis

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The Chief Executive Officer and the Chief Financial Officer of Vermilion have assessed the effectiveness of Vermilion’s internal control over financial reporting as defined in Rule 13a-15 under the US Securities Exchange Act of 1934 and as defined in Canada by National Instrument 52-109, Certification of Disclosure in Issuers’ Annual and Interim Filings. The assessment was based on the framework in *Internal Control – Integrated Framework (2013)*issued by the Committee of Sponsoring Organizations of the Treadway Commission. The Chief Executive Officer and the Chief Financial Officer of Vermilion have concluded that Vermilion’s internal control over financial reporting was effective as of December 31, 2022. The effectiveness of Vermilion’s internal control over financial reporting as of December 31, 2022 has been audited by Deloitte LLP, as reflected in their report included in the 2022 audited annual financial statements filed with the US Securities and Exchange Commission. No changes were made to Vermilion’s internal control over financial reporting during the year ended December 31, 2022, that have materially affected, or are reasonably likely to materially affect, the internal controls over financial reporting.

​

Vermilion has limited the scope of design controls and procedures ("DC&P") and internal controls over financial reporting to exclude controls, policies

and procedures of Leucrotta Exploration Inc., which was acquired on May 31, 2022. The scope limitation is in accordance with section 3.3(1)(b) of NI 52-109 which allows an issuer to limit the design of DC&P and ICFR to exclude controls, policies, and procedures of a business that the issuer acquired not more than 365 days before the end of the fiscal period.

​

The table below presents the summary financial information of Leucrotta Exploration Inc. included in Vermilion's financial statements as at and for the year ended December 31, 2022:

​

​ ​
(M) As at Dec 31, 2022
Non-current assets 659,047
Non-current liabilities 100,697
Net assets 558,350

All values are in US Dollars.

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​ ​
(M) Year Ended Dec 31, 2022
Revenue net of royalties 55,696
Net earnings 17,055

All values are in US Dollars.

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Supplemental Table 1: Netbacks

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The following table includes financial statement information on a per unit basis by business unit. Liquids includes crude oil, condensate, and NGLs. Natural gas sales volumes have been converted on a basis of six thousand cubic feet of natural gas to one barrel of oil equivalent.

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ **** Q4 2022 **** ​ **** ​ 2022 Q4 2021 2021
​ Liquids ​ Natural Gas ​ Total ​ Liquids ​ Natural Gas ​ Total ​ Total ​ Total
​ $/bbl ​ $/mcf ​ $/boe ​ $/bbl ​ $/mcf ​ $/boe ​ $/boe ​ $/boe
Canada
Sales 90.58 5.96 **** 65.13 99.07 6.07 **** 70.33 59.16 47.54
Royalties (14.09) (0.16) **** (7.99) (16.56) (0.47) **** (10.26) (8.10) (5.99)
Transportation (3.10) (0.36) **** (2.66) (2.92) (0.28) **** (2.35) (2.00) (2.04)
Operating (17.05) (1.41) **** (13.05) (16.30) (1.37) **** (12.60) (11.96) (11.35)
Operating netback 56.34 4.03 **** 41.43 63.29 3.95 **** 45.12 37.10 28.16
General and administration ​ **** ​ (1.37) ​ **** ​ (1.50) (0.71) (0.97)
Fund flows from operations (/boe) **** **** ​ 40.06 **** **** ​ 43.62 36.39 27.19
United States
Sales 96.51 6.00 **** 83.51 102.22 6.36 **** 87.46 67.18 62.98
Royalties (26.18) (1.85) **** (22.94) (27.00) (1.88) **** (23.38) (19.60) (17.23)
Transportation (0.23) — **** (0.18) (0.42) — **** (0.33) (0.61) (0.75)
Operating (17.98) (2.75) **** (17.66) (14.59) (2.29) **** (14.40) (9.22) (9.52)
Operating netback 52.12 1.40 **** 42.73 60.21 2.19 **** 49.35 37.75 35.48
General and administration ​ **** ​ (4.28) ​ **** ​ (3.08) (3.10) (2.56)
Fund flows from operations (/boe) ​ **** ​ 38.45 ​ **** ​ 46.27 34.65 32.92
France
Sales 119.68 — **** 119.68 132.90 — **** 132.90 100.18 88.15
Royalties (14.27) — **** (14.28) (14.67) — **** (14.68) (12.77) (11.89)
Transportation (7.05) — **** (7.05) (7.31) — **** (7.31) (8.25) (8.36)
Operating (19.41) — **** (19.41) (20.94) — **** (20.94) (17.88) (16.46)
Operating netback 78.95 — **** 78.94 89.98 — **** 89.97 61.28 51.44
General and administration ​ **** ​ (7.73) ​ **** ​ (5.98) (3.02) (3.46)
Current income taxes ​ **** ​ (7.69) ​ **** ​ (10.87) (4.12) 2.88
Fund flows from operations (/boe) ​ **** ​ 63.52 ​ **** ​ 73.12 54.14 50.86
Netherlands
Sales (6.47) 47.47 **** 281.75 87.13 47.04 **** 279.87 205.17 110.47
Royalties — (0.20) **** (1.21) — (0.04) **** (0.25) (0.52) (0.33)
Operating — (4.45) **** (26.44) — (3.85) **** (22.82) (14.20) (13.17)
Operating netback (6.47) 42.82 **** 254.10 87.13 43.15 **** 256.80 190.45 96.97
General and administration ​ **** ​ (4.75) ​ **** ​ (2.12) (0.88) (0.46)
Current income taxes ​ **** ​ (86.02) ​ **** ​ (74.91) (41.66) (17.40)
Fund flows from operations (/boe) ​ **** ​ 163.33 ​ **** ​ 179.77 147.91 79.11
Germany
Sales 114.67 43.24 **** 218.13 128.00 43.84 **** 231.34 164.96 98.06
Royalties (2.64) (2.52) **** (11.54) (2.66) (2.09) **** (10.21) (2.29) (2.12)
Transportation (13.67) (0.61) **** (6.53) (10.69) (0.47) **** (4.69) (5.22) (4.73)
Operating (17.53) (4.42) **** (23.96) (19.57) (3.35) **** (19.96) (18.41) (20.18)
Operating netback 80.83 35.69 **** 176.10 95.08 37.93 **** 196.48 139.04 71.03
General and administration ​ **** ​ (5.36) ​ **** ​ (3.34) (3.80) (3.91)
Current income taxes ​ ​ ​ ​ (3.53) ​ ​ ​ ​ ​ (15.15) ​ — ​ —
Fund flows from operations (/boe) ​ **** ​ 167.21 ​ **** ​ 177.99 135.24 67.12
Ireland
Sales — 27.02 **** 162.16 — 32.34 **** 194.05 236.78 120.51
Transportation — (0.31) **** (1.88) — (0.36) **** (2.14) (2.03) (2.36)
Operating — (1.96) **** (11.74) — (1.65) **** (9.92) (8.89) (8.37)
Operating netback — 24.75 **** 148.54 — 30.33 **** 181.99 225.86 109.78
General and administration ​ **** ​ (0.78) ​ **** ​ 0.07 (0.81) 0.01
Fund flows from operations (/boe) ​ ​ ​ ​ 147.76 ​ ​ ​ ​ ​ 182.06 ​ 225.05 ​ 109.79

All values are in US Dollars.

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​

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ ​ ​ Q4 2022 ​ ​ ​ ​ ​ 2022 ​ ​ Q4 2021 2021
​ **** Liquids **** Natural Gas **** Total **** Liquids **** Natural Gas **** Total **** Total **** Total
​ ​ $/bbl ​ $/mcf ​ $/boe ​ $/bbl ​ $/mcf ​ $/boe ​ $/boe ​ $/boe
Australia ​ ​ ​ ​ ​ ​
Sales ​ 139.95 — ​ 139.95 148.15 — ​ 148.15 ​ 112.26 ​ 103.01
Operating ​ (31.23) — ​ (31.23) (38.50) — ​ (38.50) ​ (44.31) ​ (36.55)
PRRT ^(1)^ ​ (7.40) — ​ (7.40) (12.27) — ​ (12.27) ​ (15.43) ​ (11.30)
Operating netback ​ 101.32 — ​ 101.32 97.38 — ​ 97.38 ​ 52.52 ​ 55.16
General and administration ​ ​ **** ​ ​ (2.93) ​ **** ​ ​ (3.32) ​ (3.07) ​ (2.49)
Current income taxes ​ ​ **** ​ ​ 3.47 ​ **** ​ ​ 3.36 ​ 6.73 ​ 4.15
Fund flows from operations ($/boe) ​ ​ **** ​ ​ 101.86 ​ **** ​ ​ 97.42 ​ 56.18 ​ 56.82
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Total Company ​ ​ ​ ​ ​
Sales ​ 103.54 17.43 ​ 103.99 110.22 18.99 ​ 111.95 ​ 96.82 ​ 66.81
Realized hedging (loss) gain ​ (0.68) (1.90) ​ (5.42) (5.82) (3.56) ​ (13.07) ​ (23.97) ​ (10.52)
Royalties ​ (12.69) (0.51) ​ (8.43) (15.24) (0.62) ​ (9.85) ​ (7.43) ​ (5.98)
Transportation ​ (3.30) (0.33) ​ (2.71) (3.39) (0.26) ​ (2.54) ​ (2.41) ​ (2.48)
Operating ​ (19.62) (2.21) ​ (16.81) (18.99) (2.01) ​ (15.75) ​ (14.24) ​ (13.27)
PRRT ^(1)^ ​ (1.12) — ​ (0.62) (1.11) — ​ (0.59) ​ (0.70) ​ (0.50)
Operating netback ​ 66.13 12.48 ​ 70.00 65.67 12.54 ​ 70.15 ​ 48.07 ​ 34.06
General and administration ​ ​ **** ​ ​ (1.65) ​ **** ​ ​ (1.86) ​ (2.20) ​ (1.70)
Interest expense ​ ​ **** ​ ​ (2.78) ​ **** ​ ​ (2.67) ​ (2.06) ​ (2.35)
Realized foreign exchange ​ ​ **** ​ ​ 2.33 ​ **** ​ ​ 0.49 ​ (0.30) ​ (0.21)
Other income ​ ​ **** ​ ​ (0.14) ​ **** ​ ​ 0.42 ​ 1.29 ​ 0.71
Corporate income taxes ​ ​ **** ​ ​ (5.18) ​ **** ​ ​ (6.70) ​ (4.07) ​ (0.97)
Windfall taxes ​ ​ ​ ​ ​ (27.50) ​ ​ ​ ​ ​ (7.18) ​ — ​ —
Fund flows from operations ($/boe) ​ ​ **** ​ ​ 35.08 ​ **** ​ ​ 52.65 ​ 40.73 ​ 29.54

​

^(1)^Vermilion considers Australian PRRT to be an operating item and, accordingly, has included PRRT in the calculation of operating netbacks. Current income taxes presented above excludes PRRT.

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Vermilion Energy Inc.  ■  Page 45  ■  2022 Management's Discussion and Analysis

​

Supplemental Table 2: Hedges

​

The prices in these tables may represent the weighted averages for several contracts with foreign currency amounts translated to the disclosure currency using forward rates as at the month-end date. The weighted average price for the portfolio of options listed below may not have the same payoff profile as the individual contracts. As such, the presentation of the weighted average prices is purely for indicative purposes.

​

The following tables outline Vermilion’s outstanding risk management positions as at December 31, 2022:

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted
​ Daily Weighted Weighted Weighted Weighted Daily Average
​ ​ ​ ​ ​ Bought ​ Average ​ Daily ​ Average ​ Daily ​ Average ​ Daily ​ Average ​ Bought ​ Bought
​ ​ ​ ​ ​ Put ​ Bought Put ​ Sold Call ​ Sold Call ​ Sold Put ​ Sold Put ​ Sold Swap ​ Sold Swap ​ Swap ​ Swap
​ ​ Unit ​ Currency Volume ​ Price ​ Volume ​ Price ​ Volume ​ Price ​ Volume ​ Price ​ Volume ​ Price
AECO
Q1 2023 ​ mcf CAD 4,739 3.69 4,739 7.70 — — 28,435 4.95 — —
Q2 2023 mcf CAD — — — — — — 14,217 4.19 — —
Q3 2023 mcf CAD — — — — — — 14,217 4.19 — —
Q4 2023 mcf CAD — — — — — — 4,791 4.19 — —
AECO Basis (AECO less NYMEX Henry Hub)
Q2 2023 mcf — — — — — — 23,000 (1.13) — —
Q3 2023 mcf — — — — — — 23,000 (1.13) — —
Q4 2023 mcf — — — — — — 7,750 (1.13) — —
NYMEX Henry Hub
Q1 2023 mcf 24,000 4.00 24,000 8.44 — — — — — —
Q2 2023 mcf 5,000 4.00 5,000 8.75 — — — — — —
Q3 2023 mcf 5,000 4.00 5,000 8.75 — — — — — —
Q4 2023 mcf 1,685 4.00 1,685 8.75 — — — — — —

All values are in US Dollars.

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted
​ **** **** **** **** Weighted **** Daily **** Weighted Weighted Weighted Daily Average
​ ​ ​ ​ ​ Daily ​ Average ​ Sold ​ Average ​ Daily ​ Average ​ Daily ​ Average ​ Bought ​ Bought
​ ​ ​ ​ ​ Bought Put ​ Bought Put ​ Call ​ Sold Call ​ Sold Put ​ Sold Put ​ Sold Swap ​ Sold Swap ​ Swap ​ Swap
​ ​ Unit ​ Currency Volume ​ Price ​ Volume ​ Price ​ Volume ​ Price ​ Volume ​ Price ​ Volume ​ Price
NBP
Q1 2023 mcf ​ 18,426 ​ 11.76 ​ 18,426 ​ 19.54 ​ 14,740 ​ 4.10 ​ — ​ — ​ — ​ —
Q2 2023 mcf ​ 7,370 ​ 11.48 ​ 7,370 ​ 17.46 ​ 4,913 ​ 4.40 ​ — ​ — ​ — ​ —
Q3 2023 mcf ​ 2,457 ​ 22.71 ​ 2,457 ​ 35.90 ​ — ​ — ​ — ​ — ​ — ​ —
Q1 2024 mcf ​ 4,913 ​ 41.03 ​ 4,913 ​ 84.26 ​ — ​ — ​ — ​ — ​ — ​ —
TTF ​ ​ ​
Q1 2023 mcf 14,740 24.01 14,740 46.12 2,457 3.52 — — — —
Q2 2023 mcf 19,654 34.53 19,654 53.21 — — — — — —
Q3 2023 mcf ​ 19,654 ​ 34.53 ​ 19,654 ​ 53.21 ​ — ​ — ​ — ​ — ​ — ​ —
Q4 2023 mcf ​ 12,284 ​ 44.84 ​ 12,284 ​ 84.99 ​ — ​ — ​ 3,685 ​ 67.41 ​ — ​ —
Q1 2024 mcf ​ 31,938 ​ 40.69 ​ 31,938 ​ 78.00 ​ — ​ — ​ 3,685 ​ 67.41 ​ — ​ —
Q2 2024 mcf ​ 3,593 ​ 37.56 ​ 3,593 ​ 74.66 ​ — ​ — ​ — ​ — ​ — ​ —
Q3 2024 mcf ​ 3,593 ​ 37.56 ​ 3,593 ​ 74.66 ​ — ​ — ​ — ​ — ​ — ​ —

All values are in Euros.

​

​ ​ ​ ​ ​ ​ ​ ​ ​
VET Equity Swaps **** ​ **** Initial Share Price ​ ​ Share Volume
Swap Jan 2020 - Apr 2023 20.9788 CAD 2,250,000
Swap Jan 2020 - Jul 2024 22.4587 CAD 1,500,000

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Cross Currency Interest Rate **** ​ **** Receive Notional Amount Receive Rate **** Pay Notional Amount **** ​ Pay Rate
Swap January 2023 111,600,000 SOFR + 1.35% 150,000,000 CAD CDOR + 0.88%

All values are in US Dollars.

​

​

​

​

Vermilion Energy Inc.  ■  Page 46  ■  2022 Management's Discussion and Analysis

​

Supplemental Table 3: Capital Expenditures and Acquisitions

​

​ ​ ​ ​ ​ ​ ​ ​
By classification (M) Q4 2022 **** Q4 2021 **** 2022 **** 2021
Drilling and development 157,849 119,002 **** 528,056 339,390
Exploration and evaluation 11,456 26,805 **** 23,761 35,406
Capital expenditures 169,305 145,807 **** 551,817 374,796
​ ​ ​ ​ ​ ​ ​ ​
Acquisitions 3,594 26,848 **** 510,309 131,628
Acquisition of securities 964 ​ — ​ 23,282 ​ —
Contingent consideration — ​ — ​ — ​ 330
Working capital assumed — ​ (3,215) ​ 6,122 ​ (993)
Acquisitions 4,558 23,633 **** 539,713 130,965

All values are in US Dollars.

​

​ ​ ​ ​ ​ ​ ​ ​
By category (M) Q4 2022 **** Q4 2021 **** 2022 **** 2021
Drilling, completion, new well equip and tie-in, workovers and recompletions 112,755 97,833 **** 418,284 252,734
Production equipment and facilities 49,286 30,919 **** 105,722 93,901
Seismic, studies, land and other 7,264 17,055 **** 27,811 28,161
Capital expenditures 169,305 145,807 **** 551,817 374,796
Acquisitions 4,558 23,633 **** 539,713 130,965
Total capital expenditures and acquisitions 173,863 169,440 **** 1,091,530 505,761

All values are in US Dollars.

​

​ ​ ​ ​ ​ ​ ​ ​
Capital expenditures by country (M) Q4 2022 **** Q4 2021 **** 2022 **** 2021
Canada 111,483 86,051 **** 275,203 190,242
United States 2,409 3,592 **** 63,353 32,540
France 15,704 15,030 **** 44,252 39,708
Netherlands 14,232 12,432 **** 21,652 27,037
Germany 10,089 10,883 **** 26,157 20,307
Ireland 1,323 105 **** 3,030 1,261
Australia 5,753 8,755 **** 95,173 34,785
Central and Eastern Europe 8,312 8,959 **** 22,997 28,916
Total capital expenditures 169,305 145,807 **** 551,817 374,796

All values are in US Dollars.

​

​ ​ ​ ​ ​ ​ ​ ​
Acquisitions by country (M) Q4 2022 **** Q4 2021 **** 2022 **** 2021
Canada 1,985 1,191 **** 531,348 1,699
United States — 78 **** 1,075 94,248
Netherlands — — **** 707 —
Germany (11) 20,485 **** 3,857 33,139
Ireland 2,584 ​ 1,879 ​ 2,726 ​ 1,879
Total acquisitions 4,558 23,633 **** 539,713 130,965

All values are in US Dollars.

​

​

Vermilion Energy Inc.  ■  Page 47  ■  2022 Management's Discussion and Analysis

​

Supplemental Table 4: Production

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ **** Q4/22 **** Q3/22 **** Q2/22 **** Q1/22 **** Q4/21 **** Q3/21 **** Q2/21 **** Q1/21 **** Q4/20 **** Q3/20 **** Q2/20 **** Q1/20
Canada
Light and medium crude oil (bbls/d) **** 17,448 16,835 17,042 15,980 **** 16,388 16,809 16,868 17,767 19,301 19,847 22,545 22,767
Condensate ^(1)^ (bbls/d) **** 4,525 4,204 4,873 4,892 **** 4,785 4,426 5,558 4,556 4,662 5,200 5,047 4,634
Other NGLs ^(1)^ (bbls/d) **** 6,279 6,870 7,155 7,286 **** 7,073 6,862 7,767 7,016 7,334 8,350 8,248 6,943
NGLs (bbls/d) **** 10,804 11,074 12,028 12,178 **** 11,858 11,288 13,325 11,572 11,996 13,550 13,295 11,577
Conventional natural gas (mmcf/d) **** 146.81 145.04 143.94 140.55 **** 128.85 138.42 146.55 138.41 135.27 155.15 164.08 151.16
Total (boe/d) **** 52,720 52,080 53,060 51,584 **** 49,720 51,168 54,618 52,407 53,840 59,256 63,187 59,537
United States
Light and medium crude oil (bbls/d) **** 3,282 2,824 2,846 2,675 **** 2,647 3,520 1,888 2,322 2,495 3,243 3,971 2,481
Condensate ^(1)^ (bbls/d) **** 36 35 40 24 **** 26 2 2 — 1 6 6 6
Other NGLs ^(1)^ (bbls/d) **** 1,218 1,031 958 1,056 **** 1,388 1,206 928 1,058 1,294 1,158 1,340 1,079
NGLs (bbls/d) **** 1,254 1,066 998 1,080 **** 1,414 1,208 930 1,058 1,295 1,164 1,346 1,085
Conventional natural gas (mmcf/d) **** 7.45 7.03 6.74 7.56 **** 9.09 6.75 5.51 5.95 6.87 7.94 8.35 6.72
Total (boe/d) **** 5,779 5,062 4,967 5,014 **** 5,575 5,854 3,736 4,373 4,934 5,730 6,708 4,685
France
Light and medium crude oil (bbls/d) **** 7,247 6,818 8,126 8,389 **** 8,453 8,677 9,013 9,062 9,255 9,347 7,046 9,957
Total (boe/d) **** 7,247 6,818 8,126 8,389 **** 8,453 8,677 9,013 9,062 9,255 9,347 7,046 9,957
Netherlands
Light and medium crude oil (bbls/d) **** — — 1 1 **** — 6 1 6 1 — 1 3
Condensate ^(1)^ (bbls/d) **** 49 74 60 83 **** 97 104 95 92 99 83 86 84
NGLs (bbls/d) **** 49 74 60 83 **** 97 104 95 92 99 83 86 84
Conventional natural gas (mmcf/d) **** 27.41 29.15 35.22 39.03 **** 51.98 42.48 37.59 41.45 42.95 46.09 47.31 48.33
Total (boe/d) **** 4,617 4,933 5,930 6,589 **** 8,761 7,190 6,362 7,006 7,257 7,764 7,972 8,143
Germany
Light and medium crude oil (bbls/d) **** 1,481 1,764 1,331 1,158 **** 1,127 1,043 1,093 911 960 964 1,039 909
Conventional natural gas (mmcf/d) **** 25.86 26.54 25.36 26.95 **** 18.00 16.19 15.60 13.40 11.50 11.25 13.23 14.64
Total (boe/d) **** 5,791 6,187 5,558 5,650 **** 4,127 3,741 3,694 3,144 2,876 2,839 3,244 3,349
Ireland
Conventional natural gas (mmcf/d) **** 26.04 25.74 27.93 30.26 **** 30.12 22.67 30.19 34.14 34.76 35.12 38.57 41.38
Total (boe/d) **** 4,340 4,290 4,655 5,043 **** 5,020 3,778 5,031 5,690 5,793 5,853 6,428 6,896
Australia
Light and medium crude oil (bbls/d) **** 4,847 4,763 2,465 3,888 **** 2,742 4,190 3,835 4,489 3,781 4,549 5,299 4,041
Total (boe/d) **** 4,847 4,763 2,465 3,888 **** 2,742 4,190 3,835 4,489 3,781 4,549 5,299 4,041
Central and Eastern Europe
Conventional natural gas (mmcf/d) **** 0.67 0.63 0.64 0.34 **** 0.12 0.22 0.28 0.63 0.67 0.80 2.89 3.27
Total (boe/d) **** 111 104 106 57 **** 20 36 46 104 111 132 483 546
Consolidated
Light and medium crude oil (bbls/d) **** 34,305 33,003 31,811 32,091 **** 31,356 34,245 32,698 34,556 35,793 37,951 39,899 40,157
Condensate ^(1)^ (bbls/d) **** 4,610 4,312 4,973 4,999 **** 4,908 4,532 5,656 4,648 4,762 5,289 5,142 4,724
Other NGLs ^(1)^ (bbls/d) **** 7,497 7,901 8,113 8,342 **** 8,461 8,068 8,695 8,074 8,627 9,509 9,588 8,022
NGLs (bbls/d) **** 12,107 12,213 13,086 13,341 **** 13,369 12,600 14,351 12,722 13,389 14,798 14,730 12,746
Conventional natural gas (mmcf/d) **** 234.23 234.12 239.83 244.69 **** 238.16 226.73 235.72 233.98 232.00 256.34 274.42 265.51
Total (boe/d) **** 85,450 84,237 84,868 86,213 **** 84,417 84,633 86,335 86,276 87,848 95,471 100,366 97,154

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Vermilion Energy Inc.  ■  Page 48  ■  2022 Management's Discussion and Analysis

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​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ **** 2022 **** 2021 **** 2020 **** 2019 **** 2018 **** 2017
Canada ​ ​ ​ ​
Light and medium crude oil (bbls/d) 16,830 ​ 16,954 ​ 21,106 23,971 17,400 6,015
Condensate ^(1)^ (bbls/d) 4,621 ​ 4,831 ​ 4,886 4,295 3,754 3,036
Other NGLs ^(1)^ (bbls/d) 6,895 ​ 7,179 ​ 7,719 6,988 5,914 4,144
NGLs (bbls/d) 11,516 ​ 12,010 ​ 12,605 11,283 9,668 7,180
Conventional natural gas (mmcf/d) 144.10 ​ 138.03 ​ 151.38 148.35 129.37 97.89
Total (boe/d) 52,364 ​ 51,968 ​ 58,942 59,979 48,630 29,510
United States **** ​ ​ ​ ​
Light and medium crude oil (bbls/d) 2,908 ​ 2,597 ​ 3,046 2,514 1,069 662
Condensate ^(1)^ (bbls/d) 34 ​ 8 ​ 5 18 8 4
Other NGLs ^(1)^ (bbls/d) 1,066 ​ 1,146 ​ 1,218 996 452 50
NGLs (bbls/d) 1,100 ​ 1,154 ​ 1,223 1,014 460 54
Conventional natural gas (mmcf/d) 7.20 ​ 6.84 ​ 7.47 6.89 2.78 0.39
Total (boe/d) 5,207 ​ 4,890 ​ 5,514 4,675 1,992 781
France **** ​ ​ ​ ​
Light and medium crude oil (bbls/d) 7,639 ​ 8,799 ​ 8,903 10,435 11,362 11,084
Conventional natural gas (mmcf/d) — ​ — ​ — 0.19 0.21 —
Total (boe/d) 7,639 ​ 8,799 ​ 8,903 10,467 11,396 11,084
Netherlands **** ​ ​ ​ ​
Light and medium crude oil (bbls/d) — ​ 3 ​ 1 3 — —
Condensate ^(1)^ (bbls/d) 66 ​ 97 ​ 88 88 90 90
NGLs (bbls/d) 66 ​ 97 ​ 88 88 90 90
Conventional natural gas (mmcf/d) 32.66 ​ 43.40 ​ 46.16 49.10 46.13 40.54
Total (boe/d) 5,510 ​ 7,334 ​ 7,782 8,274 7,779 6,847
Germany **** ​ ​ ​ ​
Light and medium crude oil (bbls/d) 1,435 ​ 1,044 ​ 968 917 1,004 1,060
Conventional natural gas (mmcf/d) 26.18 ​ 15.81 ​ 12.65 15.31 15.66 19.39
Total (boe/d) 5,798 ​ 3,679 ​ 3,076 3,468 3,614 4,291
Ireland **** ​ ​ ​ ​
Conventional natural gas (mmcf/d) 27.48 ​ 29.25 ​ 37.44 46.57 55.17 58.43
Total (boe/d) 4,579 ​ 4,875 ​ 6,240 7,762 9,195 9,737
Australia **** ​ ​ ​ ​
Light and medium crude oil (bbls/d) 3,995 ​ 3,810 ​ 4,416 5,662 4,494 5,770
Total (boe/d) 3,995 ​ 3,810 ​ 4,416 5,662 4,494 5,770
Central and Eastern Europe **** ​ ​ ​ ​
Conventional natural gas (mmcf/d) 0.57 ​ 0.31 ​ 1.90 0.42 1.02 —
Total (boe/d) 95 ​ 51 ​ 317 70 169 —
Consolidated **** ​ ​ ​ ​
Light and medium crude oil (bbls/d) 32,809 ​ 33,208 ​ 38,441 43,502 35,329 24,591
Condensate ^(1)^ (bbls/d) 4,721 ​ 4,936 ​ 4,980 4,400 3,853 3,130
Other NGLs ^(1)^ (bbls/d) 7,961 ​ 8,325 ​ 8,937 7,984 6,366 4,194
NGLs (bbls/d) 12,682 ​ 13,261 ​ 13,917 12,384 10,219 7,324
Conventional natural gas (mmcf/d) 238.18 ​ 233.64 ​ 256.99 266.82 250.33 216.64
Total (boe/d) 85,187 ​ 85,408 ​ 95,190 100,357 87,270 68,021

​

^(1)^Under National Instrument 51-101 "Standards of Disclosure for Oil and Gas Activities", disclosure of production volumes should include segmentation by product type as defined in the instrument. This table provides a reconciliation from "crude oil and condensate", "NGLs" and "natural gas" to the product types. In this report, references to "crude oil" and "light and medium crude oil" mean "light crude oil and medium crude oil" and references to "natural gas" mean "conventional natural gas". Production volumes reported are based on quantities as measured at the first point of sale.

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Vermilion Energy Inc.  ■  Page 49  ■  2022 Management's Discussion and Analysis

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Supplemental Table 5: Segmented Financial Results

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ **** Three Months Ended December 31, 2022
($M) ​ Canada **** USA **** France **** Netherlands **** Germany **** Ireland **** Australia **** Corporate **** Total
Drilling and development 111,483 2,409 15,704 13,897 9,844 1,323 5,753 (2,564) 157,849
Exploration and evaluation — — — 335 245 — — 10,876 11,456
Crude oil and condensate sales 213,382 34,786 77,910 (29) 18,153 15 95,420 — 439,637
NGL sales 22,043 5,496 — — — — — — 27,539
Natural gas sales 80,472 4,116 — 119,697 102,858 64,738 — 3,636 375,517
Sales of purchased commodities — — — — — — — 50,215 50,215
Royalties (38,747) (12,198) (9,294) (512) (6,403) — — (1,149) (68,303)
Revenue from external customers 277,150 32,200 68,616 119,156 114,608 64,753 95,420 52,702 824,605
Purchased commodities — — — — — — — (50,215) (50,215)
Transportation (12,919) (95) (4,589) — (3,621) (752) — — (21,976)
Operating (63,305) (9,389) (12,638) (11,229) (13,292) (4,687) (21,291) (416) (136,247)
General and administration (6,661) (2,274) (5,033) (2,016) (2,972) (313) (2,000) 7,925 (13,344)
PRRT — — — — — — (5,045) — (5,045)
Corporate income taxes (10) — (5,008) (36,536) (1,959) — 2,366 (811) (41,958)
Windfall taxes — — — — — — — (222,859) (222,859)
Interest expense — — — — — — — (22,506) (22,506)
Realized loss on derivative instruments ​ — ​ — ​ — ​ — ​ — ​ — ​ — ​ (43,940) ​ (43,940)
Realized foreign exchange gain — — — — — — — 18,845 18,845
Realized other expense — — — — — — — (1,140) (1,140)
Fund flows from operations **** 194,255 **** 20,442 **** 41,348 **** 69,375 **** 92,764 **** 59,001 **** 69,450 **** (262,415) **** 284,220

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ **** Year Ended December 31, 2022
($M) ​ Canada **** USA **** France **** Netherlands **** Germany **** Ireland **** Australia **** Corporate **** Total
Total assets 3,612,487 618,116 823,544 240,276 398,612 465,643 249,253 583,127 6,991,058
Drilling and development 275,203 63,353 44,250 21,629 25,087 3,030 95,173 331 528,056
Exploration and evaluation — — 2 23 1,070 — — 22,666 23,761
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Crude oil and condensate sales 910,863 130,150 365,431 2,119 62,464 15 221,187 — 1,692,229
NGL sales 114,128 19,385 — — — — — — 133,513
Natural gas sales 319,293 16,698 — 560,738 418,796 324,330 — 10,797 1,650,652
Sales of purchased commodities — — — — — — — 244,834 244,834
Royalties (196,005) (44,427) (40,353) (512) (21,232) — — (3,488) (306,017)
Revenue from external customers 1,148,279 121,806 325,078 562,345 460,028 324,345 221,187 252,143 3,415,211
Purchased commodities — — — — — — — (244,834) (244,834)
Transportation (44,849) (618) (20,100) — (9,751) (3,578) — — (78,896)
Operating (240,899) (27,372) (57,588) (45,903) (41,523) (16,580) (57,478) (1,691) (489,034)
General and administration (28,643) (5,863) (16,444) (4,255) (6,949) 122 (4,964) 9,319 (57,677)
PRRT — — — — — — (18,318) — (18,318)
Corporate income taxes (10) — (29,889) (150,647) (31,513) — 5,016 (1,110) (208,153)
Windfall taxes — — — — — — — (222,859) (222,859)
Interest expense — — — — — — — (82,858) (82,858)
Realized loss on derivative instruments ​ — ​ — ​ — ​ — ​ — ​ — ​ — ​ (405,894) ​ (405,894)
Realized foreign exchange gain ​ — ​ — ​ — ​ — ​ — ​ — ​ — ​ 15,195 ​ 15,195
Realized other income — — — — — — — 12,982 12,982
Fund flows from operations **** 833,878 **** 87,953 **** 201,057 **** 361,540 **** 370,292 **** 304,309 **** 145,443 **** (669,607) **** 1,634,865

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Vermilion Energy Inc.  ■  Page 50  ■  2022 Management's Discussion and Analysis

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​

​

Supplemental Table 6: Operational and Financial Data by Core Region

​

Production volumes ^(1)^

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ **** Q4/22 **** Q3/22 **** Q2/22 **** Q1/22 **** Q4/21 **** Q3/21 **** Q2/21 **** Q1/21 **** Q4/20 **** Q3/20 **** Q2/20 **** Q1/20
North America ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Crude oil and condensate (bbls/d) 25,291 23,898 24,801 23,571 23,846 24,757 24,316 24,645 26,459 28,296 31,569 29,888
NGLs (bbls/d) 7,497 7,901 8,113 8,342 8,461 8,068 8,695 8,074 8,628 9,508 9,588 8,022
Natural gas (mmcf/d) 154.26 152.07 150.68 148.11 137.93 145.18 152.06 144.36 142.13 163.09 172.43 157.88
Total (boe/d) **** 58,499 **** 57,142 **** 58,027 **** 56,598 **** 55,295 **** 57,022 **** 58,354 **** 56,780 **** 58,774 **** 64,986 **** 69,895 **** 64,222
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
International ​ ​ ​
Crude oil and condensate (bbls/d) 13,624 13,419 11,983 13,519 12,419 14,020 14,037 14,560 14,096 14,943 13,471 14,994
Natural gas (mmcf/d) 79.97 82.05 89.15 96.58 100.22 81.55 83.66 89.62 89.86 93.25 101.99 107.63
Total (boe/d) **** 26,953 **** 27,095 **** 26,840 **** 29,616 **** 29,123 **** 27,612 **** 27,981 **** 29,495 **** 29,073 **** 30,484 **** 30,472 **** 32,932
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Consolidated ​ ​ ​ ​
Crude oil and condensate (bbls/d) 38,915 37,315 36,784 37,090 36,264 38,777 38,354 39,204 40,555 43,240 45,041 44,881
NGLs (bbls/d) 7,497 7,901 8,113 8,342 8,461 8,068 8,695 8,074 8,627 9,509 9,588 8,022
Natural gas (mmcf/d) 234.23 234.12 239.83 244.69 238.16 226.73 235.72 233.98 232.00 256.34 274.42 265.51
Total (boe/d) **** 85,450 **** 84,237 **** 84,868 **** 86,213 **** 84,417 **** 84,633 **** 86,335 **** 86,276 **** 87,848 **** 95,471 **** 100,366 **** 97,154

​

^(1)^Please refer to Supplemental Table 4 "Production" for disclosure by product type.

​

Vermilion Energy Inc.  ■  Page 51  ■  2022 Management's Discussion and Analysis

​

Sales volumes

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ **** Q4/22 **** Q3/22 **** Q2/22 **** Q1/22 **** Q4/21 **** Q3/21 **** Q2/21 **** Q1/21 **** Q4/20 **** Q3/20 **** Q2/20 **** Q1/20
North America ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Crude oil and condensate (bbls/d) 25,291 23,897 24,801 23,571 23,845 24,757 24,316 24,645 26,459 28,297 31,569 29,888
NGLs (bbls/d) 7,497 7,901 8,113 8,342 8,461 8,068 8,695 8,074 8,628 9,508 9,588 8,022
Natural gas (mmcf/d) 154.26 152.07 150.68 148.11 137.93 145.18 152.06 144.36 142.13 163.09 172.43 157.88
Total (boe/d) **** 58,499 **** 57,142 **** 58,027 **** 56,598 **** 55,295 **** 57,022 **** 58,354 **** 56,780 **** 58,774 **** 64,986 **** 69,895 **** 64,222
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
International ​ ​ ​ ​
Crude oil and condensate (bbls/d) 16,257 11,493 11,720 12,615 13,985 15,227 13,859 11,421 15,359 15,689 12,202 17,090
Natural gas (mmcf/d) 79.97 82.05 89.15 96.58 100.22 81.55 83.66 89.62 89.86 93.25 101.99 107.63
Total (boe/d) **** 29,585 **** 25,169 **** 26,578 **** 28,712 **** 30,689 **** 28,820 **** 27,802 **** 26,357 **** 30,336 **** 31,229 **** 29,201 **** 35,028
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Consolidated
Crude oil and condensate (bbls/d) 41,547 35,391 36,522 36,186 37,830 39,985 38,174 36,066 41,818 43,985 43,771 46,977
NGLs (bbls/d) 7,497 7,901 8,113 8,342 8,461 8,068 8,695 8,074 8,627 9,509 9,588 8,022
Natural gas (mmcf/d) 234.23 234.12 239.83 244.69 238.16 226.73 235.72 233.98 232.00 256.34 274.42 265.51
Total (boe/d) **** 88,083 **** 82,312 **** 84,607 **** 85,310 **** 85,984 **** 85,841 **** 86,156 **** 83,138 **** 89,111 **** 96,217 **** 99,096 **** 99,250

​

Vermilion Energy Inc.  ■  Page 52  ■  2022 Management's Discussion and Analysis

​

Financial results

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ Q4/22 **** Q3/22 **** Q2/22 **** Q1/22 **** Q4/21 **** Q3/21 **** Q2/21 **** Q1/21 **** Q4/20 **** Q3/20 **** Q2/20 **** Q1/20
North America ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Crude oil and condensate sales (/bbl) 106.66 114.82 134.72 111.42 92.99 82.23 75.43 66.31 51.06 49.79 28.94 50.25
NGL sales (/bbl) 39.93 44.64 51.86 46.94 47.26 35.55 25.43 29.39 19.20 15.04 8.94 8.92
Natural gas sales (/mcf) 5.96 6.41 7.13 4.80 5.07 3.80 2.72 3.98 2.77 2.02 1.60 1.92
Sales (/boe) 66.95 71.24 83.34 65.88 59.97 50.40 42.30 43.08 32.51 28.94 18.24 29.22
Royalties (/boe) (9.47) (12.58) (12.51) (11.24) (9.26) (7.14) (5.98) (5.49) (3.64) (3.58) (1.67) (3.54)
Transportation (/boe) (2.42) (2.16) (2.15) (1.91) (1.86) (1.92) (1.90) (2.05) (1.92) (1.74) (1.72) (1.91)
Operating (/boe) (13.51) (14.00) (11.58) (11.95) (11.68) (11.02) (10.89) (11.21) (10.94) (7.82) (9.60) (11.93)
General and administration (/boe) 0.10 (1.27) (1.52) (1.26) (2.01) (1.14) (0.91) (1.34) (1.94) (0.78) (1.52) (0.84)
Corporate income taxes (/boe) (0.13) (0.03) — (0.02) 0.42 (0.05) (0.04) (0.04) 0.04 (0.02) (0.02) (0.04)
Fund flows from operations (/boe) 41.52 **** 41.20 **** 55.58 **** 39.50 **** 35.58 **** 29.13 **** 22.58 **** 22.95 **** 14.11 **** 15.00 **** 3.71 **** 10.96
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Fund flows from operations 223,443 216,579 293,470 201,193 180,979 152,764 119,916 117,227 76,375 89,635 23,639 64,048
Drilling and development (113,892) ​ (112,238) ​ (54,913) ​ (57,513) ​ (89,643) ​ (35,179) ​ (38,847) ​ (59,113) ​ (33,781) ​ (9,575) ​ (23,979) ​ (197,926)
Free cash flow 109,551 **** 104,341 **** 238,557 **** 143,680 **** 91,336 **** 117,585 **** 81,069 **** 58,114 **** 42,594 **** 80,060 **** (340) **** (133,878)
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
International
Crude oil and condensate sales (/bbl) 128.02 140.09 146.67 136.69 103.53 94.91 85.41 81.40 62.65 58.19 50.27 73.35
Natural gas sales (/mcf) 39.54 58.55 32.33 36.75 35.54 18.82 9.83 7.98 6.27 2.91 2.28 4.44
Sales (/boe) 177.23 254.86 173.14 183.66 163.23 103.39 72.16 62.39 50.30 37.94 28.98 49.42
Royalties (/boe) (6.38) (7.21) (7.23) (5.43) (4.13) (4.52) (3.83) (3.53) (3.02) (3.32) (2.16) (3.27)
Transportation (/boe) (3.29) (3.51) (3.64) (2.91) (3.40) (3.47) (4.64) (2.76) (2.40) (2.28) (2.04) (1.94)
Operating (/boe) (23.35) (22.63) (22.11) (19.86) (18.86) (17.55) (16.56) (16.42) (16.99) (15.18) (14.35) (16.13)
General and administration (/boe) (5.09) (3.34) (3.16) (3.02) (2.53) (2.40) (2.61) (2.06) (2.92) (2.53) (2.72) (2.63)
Corporate income taxes (/boe) (15.15) (21.97) (28.73) (17.63) (12.17) 0.64 (0.19) 0.66 2.25 0.04 (0.02) (0.11)
PRRT (/boe) (1.85) (1.96) (0.83) (2.60) (1.96) (2.74) (0.58) (0.60) (1.45) (1.27) (1.21) (2.90)
Fund flows from operations (/boe) 122.12 **** 194.24 **** 107.44 **** 132.21 **** 120.18 **** 73.35 **** 43.75 **** 37.68 **** 25.77 **** 13.40 **** 6.48 **** 22.44
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Fund flows from operations 332,377 449,771 259,840 341,626 339,286 194,505 110,654 89,403 71,934 38,498 17,193 71,526
Drilling and development (43,957) ​ (65,640) ​ (54,575) ​ (25,328) ​ (29,359) ​ (27,994) ​ (38,856) ​ (20,399) ​ (19,122) ​ (20,187) ​ (18,404) ​ (29,507)
Exploration and evaluation (11,456) ​ (6,137) ​ (3,665) ​ (2,503) ​ (26,805) ​ (3,277) ​ (1,473) ​ (3,851) ​ (6,991) ​ (1,568) ​ 109 ​ (6,271)
Free cash flow 276,964 **** 377,994 **** 201,600 **** 313,795 **** 283,122 **** 163,234 **** 70,325 **** 65,153 **** 45,821 **** 16,743 **** (1,102) **** 35,748
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ Q4/22 **** Q3/22 **** Q2/22 **** Q1/22 **** Q4/21 **** Q3/21 **** Q2/21 **** Q1/21 **** Q4/20 **** Q3/20 **** Q2/20 **** Q1/20
Consolidated
Crude oil and condensate sales (/bbl) 115.02 123.02 138.55 120.23 96.88 87.05 79.06 71.09 55.31 52.79 34.89 58.66
NGL sales (/bbl) 39.93 44.64 51.86 46.94 47.26 35.55 25.43 29.39 19.20 15.04 8.94 8.92
Natural gas sales (/mcf) 17.43 24.68 16.50 17.41 17.89 9.20 5.24 5.51 4.13 2.34 1.85 2.94
Sales (/boe) 103.99 127.39 111.55 105.52 96.82 68.19 51.93 49.20 38.57 31.86 21.40 36.35
Royalties (/boe) (8.43) (10.94) (10.85) (9.29) (7.43) (6.26) (5.29) (4.87) (3.43) (3.50) (1.81) (3.45)
Transportation (/boe) (2.71) (2.57) (2.62) (2.25) (2.41) (2.44) (2.78) (2.27) (2.08) (1.92) (1.81) (1.92)
Operating (/boe) (16.81) (16.64) (14.89) (14.61) (14.24) (13.21) (12.72) (12.86) (13.00) (10.21) (11.00) (13.41)
General and administration (/boe) (1.65) (1.90) (2.04) (1.85) (2.20) (1.56) (1.46) (1.57) (2.27) (1.35) (1.88) (1.47)
Corporate income taxes (/boe) (5.18) (6.74) (9.03) (5.95) (4.07) 0.18 (0.09) 0.18 0.80 — (0.02) (0.06)
Windfall taxes (/boe) (27.50) — — — — — — — — — — —
PRRT (/boe) (0.62) (0.60) (0.26) (0.87) (0.70) (0.92) (0.19) (0.19) (0.49) (0.41) (0.36) (1.02)
Interest (/boe) (2.78) (3.23) (2.74) (1.93) (2.06) (2.37) (2.41) (2.57) (2.42) (1.97) (1.98) (2.21)
Realized derivatives (/boe) (5.42) (18.22) (10.36) (18.78) (23.97) (9.19) (5.05) (3.43) 0.10 0.47 6.07 5.47
Realized foreign exchange (/boe) 2.33 (0.28) (0.30) 0.10 (0.30) 0.37 (0.25) (0.69) 0.16 (0.31) 0.44 0.94
Realized other (/boe) (0.14) 0.80 0.36 0.70 1.29 0.48 0.35 0.73 0.56 0.29 0.03 (0.37)
Fund flows from operations (/boe) 35.08 ​ 67.07 ​ 58.82 ​ 50.79 ​ 40.73 **** 33.27 **** 22.04 **** 21.66 **** 16.50 **** 12.95 **** 9.08 **** 18.85
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Fund flows from operations 284,220 507,876 452,901 389,868 322,173 262,696 172,942 162,051 135,212 114,776 81,852 170,225
Drilling and development (157,849) ​ (177,878) ​ (109,488) ​ (82,841) ​ (119,002) ​ (63,173) ​ (77,703) ​ (79,512) ​ (52,903) ​ (29,762) ​ (42,383) ​ (227,433)
Exploration and evaluation (11,456) ​ (6,137) ​ (3,665) ​ (2,503) ​ (26,805) ​ (3,277) ​ (1,473) ​ (3,851) ​ (6,991) ​ (1,568) ​ 109 ​ (6,271)
Free cash flow 114,915 **** 323,861 **** 339,748 **** 304,524 **** 176,366 **** 196,246 **** 93,766 **** 78,688 **** 75,318 **** 83,446 **** 39,578 **** (63,479)

All values are in US Dollars.

​

​

​

Vermilion Energy Inc.  ■  Page 53  ■  2022 Management's Discussion and Analysis

​

Non-GAAP and Other Specified Financial Measures

​

This MD&A includes references to certain financial measures which do not have standardized meanings and may not be comparable to similar measures presented by other issuers. These financial measures include fund flows from operations, a total of segments measure of profit or loss in accordance with IFRS 8 “Operating Segments” (please see Segmented Information in the Notes to the condensed Consolidated Financial Statements) and net debt, a capital management measure in accordance with IAS 1 “Presentation of Financial Statements” (please see Capital Disclosures in the Notes to the condensed Consolidated Financial Statements).

​

In addition, this MD&A includes financial measures which are not specified, defined, or determined under IFRS and are therefore considered non-GAAP financial measures and may not be comparable to similar measures presented by other issuers. These non-GAAP financial measures include:

​

Total of Segments Measure

​

Fund flows from operations (FFO): Most directly comparable to net earnings, FFO is comprised of sales excluding royalties, transportation, operating, G&A, corporate income tax, PRRT, windfall taxes, interest expense, realized loss on derivatives, realized foreign exchange gain (loss), and realized other income. The measure is used to assess the contribution of each business unit to Vermilion's ability to generate income necessary to pay dividends, repay debt, fund asset retirement obligations and make capital investments. Reconciliation to the primary financial statement measures can be found below.

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Q4 2022 Q4 2021 2022 2021
​ **** M /boe M /boe M /boe M $/boe
Sales **** 842,693 103.99 765,915 96.82 3,476,394 111.95 2,079,761 66.81
Royalties **** (68,303) (8.43) (58,785) (7.43) (306,017) (9.85) (186,122) (5.98)
Transportation **** (21,976) (2.71) (19,033) (2.41) (78,896) (2.54) (77,161) (2.48)
Operating **** (136,247) (16.81) (112,680) (14.24) (489,034) (15.75) (413,013) (13.27)
General and administration **** (13,344) (1.65) (17,374) (2.20) (57,677) (1.86) (52,877) (1.70)
Corporate income tax expense **** (41,958) (5.18) (32,234) (4.07) (208,153) (6.70) (30,166) (0.97)
Windfall taxes ​ (222,859) (27.50) — — (222,859) (7.18) — —
PRRT **** (5,045) (0.62) (5,544) (0.70) (18,318) (0.59) (15,688) (0.50)
Interest expense **** (22,506) (2.78) (16,279) (2.06) (82,858) (2.67) (73,075) (2.35)
Realized loss on derivatives **** (43,940) (5.42) (189,598) (23.97) (405,894) (13.07) (327,384) (10.52)
Realized foreign exchange gain (loss) **** 18,845 2.33 (2,395) (0.30) 15,195 0.49 (6,613) (0.21)
Realized other (expense) income **** (1,140) (0.14) 10,180 1.29 12,982 0.42 22,200 0.71
Fund flows from operations **** 284,220 35.08 322,173 40.73 1,634,865 52.65 919,862 29.54
Equity based compensation ​ (5,377) ​ (6,666) ​ (44,390) ​ (41,565) ​
Unrealized gain (loss) on derivative instruments ^(1)^ ​ 549,693 ​ 172,265 ​ 540,801 ​ (181,094) ​
Unrealized foreign exchange (loss) gain ^(1)^ ​ (47,405) ​ 7,122 ​ (84,464) ​ (64,963) ​
Accretion ​ (16,501) ​ (10,983) ​ (58,170) ​ (43,552) ​
Depletion and depreciation ​ (171,926) ​ (148,216) ​ (577,134) ​ (571,688) ​
Deferred tax expense ​ (196,733) ​ (14,834) ​ (288,707) ​ (187,343) ​
Gain on business combinations ​ — ​ — ​ — ​ 17,198 ​
Impairment reversal ​ — ​ 23,922 ​ 192,094 ​ 1,302,619 ​
Unrealized other expense ^(1)^ ​ (563) ​ (195) ​ (1,833) ​ (778) ​
Net earnings ​ 395,408 ​ 344,588 ​ 1,313,062 ​ 1,148,696 ​

All values are in US Dollars.

​

^(^^1)^ Unrealized gain (loss) on derivative instruments, Unrealized foreign exchange (loss) gain, and Unrealized other expense are line items from the respective Consolidated Statements of Cash Flows.

Vermilion Energy Inc.  ■  Page 54  ■  2022 Management's Discussion and Analysis

​

Non-GAAP Financial Measures and Non-GAAP Ratios

​

Free cash flow: Most directly comparable to cash flows from operating activities and is comprised of fund flows from operations less drilling and development costs and exploration and evaluation costs. The measure is used to determine the funding available for investing and financing activities including payment of dividends, repayment of long-term debt, reallocation into existing business units and deployment into new ventures. Reconciliation to the primary financial statement measures can be found in the following table.

​

​ ​ ​ ​ ​ ​ ​ ​
(M) Q4 2022 **** Q4 2021 **** 2022 **** 2021
Cash flows from operating activities 495,195 250,352 **** 1,814,220 834,453
Changes in non-cash operating working capital (227,483) 58,782 **** (216,869) 56,884
Asset retirement obligations settled 16,508 13,039 **** 37,514 28,525
Fund flows from operations 284,220 322,173 **** 1,634,865 919,862
Drilling and development (157,849) (119,002) **** (528,056) (339,390)
Exploration and evaluation (11,456) (26,805) **** (23,761) (35,406)
Free cash flow 114,915 176,366 **** 1,083,048 545,066

All values are in US Dollars.

​

Capital expenditures: Calculated as the sum of drilling and development costs and exploration and evaluation costs from the Consolidated Statements of Cash Flows that is most directly comparable to cash flows used in investing activities. We consider capital expenditures to be a useful measure of our investment in our existing asset base. Capital expenditures are also referred to as E&D capital. Reconciliation to the primary financial statement measures can be found below.

​

​ ​ ​ ​ ​ ​ ​ ​
(M) Q4 2022 **** Q4 2021 **** 2022 **** 2021
Drilling and development 157,849 119,002 **** 528,056 339,390
Exploration and evaluation 11,456 26,805 **** 23,761 35,406
Capital expenditures 169,305 145,807 **** 551,817 374,796

All values are in US Dollars.

​

Payout and payout % of FFO: A non-GAAP financial measure and non-GAAP ratio respectively, most directly comparable to dividends declared. Payout is comprised of dividends declared plus drilling and development costs, exploration and evaluation costs, and asset retirement obligations settled, and payout % of FFO is calculated as payout over FFO (total of segments measure). The measure is used to assess the amount of cash distributed back to shareholders and reinvested in the business for maintaining production and organic growth. The reconciliation of the measure to the primary financial statement measure can be found below.

​

​ ​ ​ ​ ​ ​ ​ ​ ​
(M) Q4 2022 **** Q4 2021 **** 2022 **** 2021 ****
Dividends declared 13,058 — **** 45,769 — ​
Drilling and development 157,849 119,002 **** 528,056 339,390 ​
Exploration and evaluation 11,456 26,805 **** 23,761 35,406 ​
Asset retirement obligations settled 16,508 13,039 **** 37,514 28,525 ​
Payout 198,871 158,846 **** 635,100 403,321 ​
% of fund flows from operations 70 % 49 % 39 % 44 %

All values are in US Dollars.

​

Return on capital employed (ROCE): A non-GAAP ratio, ROCE is a measure that we use to analyze our profitability and the efficiency of our capital allocation process; the comparable primary financial statement measure is earnings before income taxes. ROCE is calculated by dividing net earnings before interest and taxes ("EBIT") by average capital employed over the preceding twelve months. Capital employed is calculated as total assets less current liabilities while average capital employed is calculated using the balance sheets at the beginning and end of the twelve-month period.

​

​ ​ ​ ​ ​ ​
​ **** Twelve Months Ended
($M) ​ Dec 31, 2022 **** Dec 31, 2021 ****
Net earnings **** 1,313,062 1,148,696 ​
Taxes **** 738,037 233,197 ​
Interest expense **** 82,858 73,075 ​
EBIT **** 2,133,957 1,454,968 ​
Average capital employed **** 5,628,762 4,417,260 ​
Return on capital employed **** 38 % 33 %

​

Vermilion Energy Inc.  ■  Page 55  ■  2022 Management's Discussion and Analysis

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Adjusted working capital: Defined as current assets less current liabilities, excluding current derivatives and current lease liabilities. The measure is used to calculate net debt, a capital management measure disclosed below.

​

​ ​ ​ ​
​ As at
(M) Dec 31, 2022 **** Dec 31, 2021
Current assets 714,446 472,845
Current derivative asset (162,843) (19,321)
Current liabilities (892,045) (746,813)
Current lease liability 19,486 15,032
Current derivative liability 55,845 268,973
Adjusted working capital (265,111) (9,284)

All values are in US Dollars.

​

Capital Management Measure

​

Net debt: Is in accordance with IAS 1 "Presentation of Financial Statements" that is most directly comparable to long-term debt. Net debt is comprised of long-term debt (excluding unrealized foreign exchange on swapped USD borrowings) plus adjusted working capital (defined as current assets less current liabilities, excluding current derivatives and current lease liabilities), and represents Vermilion's net financing obligations after adjusting for the timing of working capital fluctuations. Net debt excludes lease obligations which are secured by a corresponding right-of-use asset.

​

​ ​ ​ ​
​ As at
(M) Dec 31, 2022 Dec 31, 2021
Long-term debt 1,081,351 1,651,569
Adjusted working capital 265,111 ​ 9,284
Unrealized FX on swapped borrowings (1,876) ​ (16,067)
Net debt 1,344,586 1,644,786
​ ​ ​
Ratio of net debt to four quarter trailing fund flows from operations 0.8 1.8

All values are in US Dollars.

​

Supplementary Financial Measures

​

Diluted shares outstanding: The sum of shares outstanding at the period end plus outstanding awards under the LTIP, based on current estimates of future performance factors and forfeiture rates.

​

​ ​ ​ ​ ​
('000s of shares) **** Q4 2022 **** Q4 2021
Shares outstanding **** 163,227 162,261
Potential shares issuable pursuant to the LTIP **** 5,389 6,485
Diluted shares outstanding **** 168,616 168,746

​

Fund flows from operations per basic and diluted share:  Management assesses fund flows from operations on a per share basis as we believe this provides a measure of our operating performance after taking into account the issuance and potential future issuance of Vermilion common shares. Fund flows from operations per basic share is calculated by dividing fund flows from operations (total of segments measure) by the basic weighted average shares outstanding as defined under IFRS. Fund flows from operations per diluted share is calculated by dividing fund flows from operations by the sum of basic weighted average shares outstanding and incremental shares issuable under the equity based compensation plans as determined using the treasury stock method.

​

Operating netback: Most directly comparable to net earnings that is calculated as sales less royalties, operating expense, transportation costs, PRRT, and realized hedging gains and losses presented on a per unit basis. Management assesses operating netback as a measure of the profitability and efficiency of our field operations.

​

Fund flows from operations per boe: Calculated as FFO (total of segments measure) by boe production. Fund flows from operations netback is used by management to assess the profitability of our business units and Vermilion as a whole.

​

Net debt to four quarter trailing fund flows from operations: Calculated as net debt (capital management measure) over the FFO (total of segments measure) from the preceding four quarters. The measure is used to assess the ability to repay debt.

​

Vermilion Energy Inc.  ■  Page 56  ■  2022 Management's Discussion and Analysis

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Acquisitions: The sum of acquisitions from the Consolidated Statements of Cash Flows, Vermilion common shares issued as consideration, the estimated value of contingent consideration, the amount of acquiree's outstanding long-term debt assumed plus or net of acquired working capital deficit or surplus. We believe that including these components provides a useful measure of the economic investment associated with our acquisition activity. A reconciliation to the acquisitions line item in the Consolidated Statements of Cash Flows can be found in Supplemental Table 3 of this MD&A.

​

Cash dividends per share: Represents cash dividends declared per share that is a useful measure of the dividends a common shareholder was entitled to during the period.

​

Covenants: The financial covenants on our revolving credit facility contain non-GAAP measures. The definitions for these financial covenants are included in Financial Position Review.

​

​

​

Vermilion Energy Inc.  ■  Page 57  ■  2022 Management's Discussion and Analysis

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​

DIRECTORS OFFICERS / CORPORATE SECRETARY AUDITORS
​ ​ ​ ​ ​
Robert Michaleski ^1,3,5^ ​ Dion Hatcher * ​ Deloitte LLP
Calgary, Alberta ​ President & Chief Executive Officer ​ Calgary, Alberta
​ ​ ​ ​ ​
Dion Hatcher ​ Lars Glemser * ​ BANKERS
Calgary, Alberta ​ Vice President & Chief Financial Officer ​ ​
​ ​ ​ ​ ​
James J. Kleckner Jr. ^7,9^ ​ Terry Hergott ​ The Toronto-Dominion Bank
Edwards, Colorado ​ Vice President Marketing ​ ​
​ ​ ​ ​ ​
Carin Knickel ^4,7,11^ ​ Yvonne Jeffery ​ Alberta Treasury Branches
Golden, Colorado ​ Vice President Sustainability ​ ​
​ ​ ​ ​ ​
Stephen P. Larke ^3,5,10^ ​ Darcy Kerwin * ​ Bank of America N.A., Canada Branch
Calgary, Alberta ​ Vice President International & HSE ​ ​
​ ​ ​ ​ Canadian Imperial Bank of Commerce
Timothy R. Marchant ^6,9,11^ ​ Bryce Kremnica * ​ ​
Calgary, Alberta ​ Vice President North America ​ Export Development Canada
​ ​ ​ ​ ​
William Roby ^7,8,11^ ​ Geoff MacDonald ​ National Bank of Canada
Katy, Texas ​ Vice President Geosciences ​ ​
​ ​ ​ ​ Royal Bank of Canada
Manjit Sharma ^2,5^ ​ Kyle Preston ​ ​
Toronto, Ontario ​ Vice President Investor Relations ​ The Bank of Nova Scotia
​ ​ ​ ​ ​
Myron Stadnyk ^7,9^ ​ Averyl Schraven ​ Wells Fargo Bank N.A., Canadian Branch
Calgary, Alberta ​ Vice President People and Culture ​ ​
​ ​ ​ ​ La Caisse Centrale Desjardins du Québec
Judy Steele ^3,5,11^ ​ Jenson Tan * ​ ​
Halifax, Nova Scotia ​ Vice President Business Development ​ Citibank N.A., Canadian Branch - Citibank Canada
​ ​ ​ ​ ​
​ Gerard Schut * ​ Canadian Western Bank
1<br><br>Chairman (Independent) ​ Vice President European Operations ​ ​
2<br><br>Audit Committee Chair (Independent) ​ Robert (Bob) J. Engbloom ​ JPMorgan Chase Bank, N.A., Toronto Branch
3<br><br>Audit Committee Member (Independent) ​ Corporate Secretary ​ ​
4<br><br>Governance and Human Resources Committee Chair (Independent) ​ * Executive Committee ​ Goldman Sachs Lending Partners LLC
5<br><br>Governance and Human Resources Committee Member (Independent) ​ ​ ​ ​
6<br><br>Health, Safety and Environment Committee Chair (Independent) ​ ​ ​ EVALUATION ENGINEERS
7<br><br>Health, Safety and Environment Committee Member (Independent) ​ ​ ​ ​
8<br><br>Independent Reserves Committee Chair (Independent) ​ ​ GLJ Petroleum Consultants Ltd.
9<br><br>Independent Reserves Committee Member (Independent) ​ ​ ​ Calgary, Alberta
10<br><br>Sustainability Committee Chair (Independent) ​ ​ ​ ​
11<br><br>Sustainability Committee Member (Independent) ​ ​ ​ ​
​ ​ ​ ​ LEGAL COUNSEL
​ ​ ​ ​ ​
​ ​ ​ ​ Norton Rose Fulbright Canada LLP
​ ​ ​ ​ Calgary, Alberta
​ ​ ​ ​ ​
​ ​ ​ ​ TRANSFER AGENT
​ ​ ​ ​ ​
​ ​ ​ ​ Odyssey Trust Company
​ ​ ​ ​ ​
​ ​ ​ ​ STOCK EXCHANGE LISTINGS
​ ​ ​ ​ ​
​ ​ ​ ​ The Toronto Stock Exchange (“VET”)
​ ​ ​ ​ The New York Stock Exchange (“VET”)
​ ​ ​ ​ ​
​ ​ ​ ​ INVESTOR RELATIONS
​ ​ ​ ​ Kyle Preston
​ ​ ​ ​ Vice President Investor Relations
​ ​ ​ ​ 403-476-8431 TEL
​ ​ ​ ​ 403-476-8100 FAX
​ ​ ​ ​ 1-866-895-8101 IR TOLL FREE
​ ​ ​ ​ investor_relations@vermilionenergy.com
​ ​ ​ ​ ​
​ ​ ​ ​

​

Vermilion Energy Inc.  ■  Page 58  ■  2022 Management's Discussion and Analysis

​

​

Exhibit 99.3

​

Disclaimer

Certain statements included or incorporated by reference in this document may constitute forward-looking statements or information under applicable securities legislation. Such forward-looking statements or information typically contain statements with words such as "anticipate", "believe", "expect", "plan", "intend", "estimate", "propose", or similar words suggesting future outcomes or statements regarding an outlook. Forward looking statements or information in this document may include, but are not limited to: capital expenditures and Vermilion’s ability to fund such expenditures; Vermilion’s additional debt capacity providing it with additional working capital; statements regarding the return of capital, the flexibility of Vermilion’s capital program and operations; business strategies and objectives; operational and financial performance; estimated volumes of reserves and resources; petroleum and natural gas sales; future production levels and the timing thereof, including Vermilion’s 2023 guidance, and rates of average annual production growth; the effect of changes in crude oil and natural gas prices, changes in exchange and inflation rates; significant declines in production or sales volumes due to unforeseen circumstances; the effect of possible changes in critical accounting estimates; statements regarding the growth and size of Vermilion’s future project inventory wells expected to be drilled in 2023; exploration and development plans and the timing thereof; Vermilion’s ability to reduce its debt; statements regarding Vermilion’s hedging program, its plans to add to its hedging positions, and the anticipated impact of Vermilion’s hedging program on project economics and free cash flows; the potential financial impact of climate-related risks; acquisition and disposition plans and the timing thereof; operating and other expenses, including the payment and amount of future dividends; royalty and income tax rates and Vermilion’s expectations regarding future taxes and taxability; and the timing of regulatory proceedings and approvals.

​

Such forward-looking statements or information are based on a number of assumptions, all or any of which may prove to be incorrect. In addition to any other assumptions identified in this document, assumptions have been made regarding, among other things: the ability of Vermilion to obtain equipment, services and supplies in a timely manner to carry out its activities in Canada and internationally; the ability of Vermilion to market crude oil, natural gas liquids, and natural gas successfully to current and new customers; the timing and costs of pipeline and storage facility construction and expansion and the ability to secure adequate product transportation; the timely receipt of required regulatory approvals; the ability of Vermilion to obtain financing on acceptable terms; foreign currency exchange rates and interest rates; future crude oil, natural gas liquids, and natural gas prices; and management’s expectations relating to the timing and results of exploration and development activities.

​

Although Vermilion believes that the expectations reflected in such forward-looking statements or information are reasonable, undue reliance should not be placed on forward-looking statements because Vermilion can give no assurance that such expectations will prove to be correct. Financial outlooks are provided for the purpose of understanding Vermilion’s financial position and business objectives, and the information may not be appropriate for other purposes. Forward-looking statements or information are based on current expectations, estimates, and projections that involve a number of risks and uncertainties which could cause actual results to differ materially from those anticipated by Vermilion and described in the forward-looking statements or information. These risks and uncertainties include, but are not limited to: the ability of management to execute its business plan; the risks of the oil and gas industry, both domestically and internationally, such as operational risks in exploring for, developing and producing crude oil, natural gas liquids, and natural gas; risks and uncertainties involving geology of crude oil, natural gas liquids, and natural gas deposits; risks inherent in Vermilion's marketing operations, including credit risk; the uncertainty of reserves estimates and reserves life and estimates of resources and associated expenditures; the uncertainty of estimates and projections relating to production and associated expenditures; potential delays or changes in plans with respect to exploration or development projects; Vermilion's ability to enter into or renew leases on acceptable terms; fluctuations in crude oil, natural gas liquids, and natural gas prices, foreign currency exchange rates, interest rates, and inflation rates; health, safety, and environmental risks; uncertainties as to the availability and cost of financing; the ability of Vermilion to add production and reserves through exploration and development activities; the possibility that government policies or laws may change or governmental approvals may be delayed or withheld; uncertainty in amounts and timing of royalty payments; risks associated with existing and potential future law suits and regulatory actions against or involving Vermilion; and other risks and uncertainties described elsewhere in this document or in Vermilion's other filings with Canadian securities regulatory authorities.

​

The forward-looking statements or information contained in this document are made as of the date hereof and Vermilion undertakes no obligation to update publicly or revise any forward-looking statements or information, whether as a result of new information, future events, or otherwise, unless required by applicable securities laws.

​

This document contains references to sustainability/ESG data and performance that reflect metrics and concepts that are commonly used in such frameworks as the Global Reporting Initiative, the Task Force on Climate-related Financial Disclosures, and the Sustainability Accounting Standards Board. Vermilion has used best efforts to align with the most commonly accepted methodologies for ESG reporting, including with respect to climate data and information on potential future risks and opportunities, in order to provide a fuller context for our current and future operations. However, these methodologies are not yet standardized, are frequently based on calculation factors that change over time, and continue to evolve rapidly. Readers are particularly cautioned to evaluate the underlying definitions and measures used by other companies, as these may not be comparable to Vermilion’s. While Vermilion will continue to monitor and adapt its reporting accordingly, the Company is not under any duty to update or revise the related sustainability/ESG data or statements except as required by applicable securities laws.

​

Vermilion Energy Inc.  ∎ Page 1 ∎  2022 Financial Statements

​

All crude oil and natural gas reserve and resource information contained in this document has been prepared and presented in accordance with National Instrument 51-101 Standards of Disclosure for Oil and Gas Activities and the Canadian Oil and Gas Evaluation Handbook. Reserves estimates have been made assuming that development of each property in respect of which the estimate is made will occur, without regard to the likely availability of funding required for such development. The actual crude oil and natural gas reserves and future production will be greater than or less than the estimates provided in this document.

​

Natural gas volumes have been converted on the basis of six thousand cubic feet of natural gas to one barrel of oil equivalent. Barrels of oil equivalent (boe) may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet to one barrel of oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead.

​

Financial data contained within this document are reported in Canadian dollars unless otherwise stated.

​

Vermilion Energy Inc.  ∎ Page 2 ∎  2022 Financial Statements

Abbreviations

​

$M thousand dollars
$MM million dollars
AECO the daily average benchmark price for natural gas at the AECO ‘C’ hub in Alberta
bbl(s) barrel(s)
bbls/d barrels per day
boe barrel of oil equivalent, including: crude oil, condensate, natural gas liquids, and natural gas (converted on the basis of one boe for six mcf of natural gas)
boe/d barrel of oil equivalent per day
GJ gigajoules
LSB light sour blend crude oil reference price
mbbls thousand barrels
mcf thousand cubic feet
mmcf/d million cubic feet per day
NBP the reference price paid for natural gas in the United Kingdom at the National Balancing Point Virtual Trading Point
NGLs natural gas liquids, which includes butane, propane, and ethane
PRRT Petroleum Resource Rent Tax, a profit based tax levied on petroleum projects in Australia
tCO2e tonnes of carbon dioxide equivalent
TTF the price for natural gas in the Netherlands, quoted in megawatt hours of natural gas, at the Title Transfer Facility Virtual Trading Point
WTI West Texas Intermediate, the reference price paid for crude oil of standard grade in US dollars at Cushing, Oklahoma

​

​

Vermilion Energy Inc.  ∎ Page 3 ∎  2022 Financial Statements

​

Management’s Report to Shareholders

Management’s Responsibility for Financial Statements

​

The accompanying consolidated financial statements of Vermilion Energy Inc. are the responsibility of management and have been approved by the Board of Directors of Vermilion Energy Inc. The consolidated financial statements have been prepared in accordance with the accounting policies detailed in the notes to the consolidated financial statements and are prepared in accordance with International Financial Reporting Standards as issued by the International Accounting Standards Board. Where necessary, management has made informed judgments and estimates of transactions that were not yet completed at the balance sheet date. Financial information throughout the Annual Report is consistent with the consolidated financial statements.

Management ensures the integrity of the consolidated financial statements by maintaining high-quality systems of internal control. Procedures and policies are designed to provide reasonable assurance that assets are safeguarded and transactions are properly recorded, and that the financial records are reliable for preparation of the consolidated financial statements. Deloitte LLP, Vermilion’s Independent Registered Public Accounting Firm, have conducted an audit of the consolidated financial statements in accordance with the standards of the Public Company Accounting Oversight Board (United States) and have provided their report.

The Board of Directors is responsible for ensuring that management fulfills its responsibility for financial reporting and internal control. The Board carries out this responsibility principally through the Audit Committee, which is appointed by the Board and is comprised entirely of independent Directors. The Committee meets periodically with management and Deloitte LLP to satisfy itself that each party is properly discharging its responsibilities and to review the consolidated financial statements, Management’s Discussion and Analysis and the Report of the Independent Registered Public Accounting Firm before they are presented to the Board of Directors.

​

Management’s Report on Internal Control Over Financial Reporting

Management is responsible for establishing and maintaining an adequate system of internal control over financial reporting. Management, under the supervision and with the participation of the principal executive officer and principle financial officer, conducted an evaluation of the effectiveness of the system of internal control over financial reporting based on the criteria established in “Internal Control - Integrated Framework (2013)” issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on this evaluation, management has assessed the effectiveness of Vermilion’s internal control over financial reporting as defined in Rule 13a-15(f) and 15d-15(f) under the US Securities Exchange Act of 1934 and as defined in Canada by National Instrument 52-109, Certification of Disclosure in Issuers’ Annual and Interim Filings. Management concluded that Vermilion’s internal control over financial reporting was effective as of December 31, 2022. Vermilion has limited the scope of design controls and procedures ("DC&P") and internal controls over financial reporting to exclude controls, policies and procedures of Leucrotta Exploration Inc., which was acquired on May 31, 2022. The scope limitation is in accordance with section 3.3(1)(b) of NI 52-109 which allows an issuer to limit the design of DC&P and ICFR to exclude controls, policies, and procedures of a business that the issuer acquired not more than 365 days before the end of the fiscal period. Total assets and revenues excluded from management's assessment of internal control over financial reporting represents 8% and 2%, respectively, of the related Consolidated Financial Statement amounts as at and for the year ended December 31, 2022.

Because of inherent limitations, internal control over financial reporting may not prevent or detect misstatements and even those systems determined to be effective can provide only reasonable assurance with respect to the financial statement preparation and presentation.

The effectiveness of Vermilion’s internal control over financial reporting as of December 31, 2022 has been audited by Deloitte LLP, the Company’s Independent Registered Public Accounting Firm, who also audited the Company’s consolidated financial statements for the year ended December 31, 2022.

(“Dion Hatcher”) (“Lars Glemser”)
​ ​
Dion Hatcher Lars Glemser
President & Chief Executive Officer Vice President & Chief Financial Officer
March 8, 2023

​

​

​

Vermilion Energy Inc.  ∎ Page 4 ∎  2022 Financial Statements

​

Report of Independent Registered Public Accounting Firm

To the Shareholders and the Board of Directors of Vermilion Energy Inc.

Opinion on Internal Control over Financial Reporting

We have audited the internal control over financial reporting of Vermilion Energy Inc. and subsidiaries (the “Company”) as of December 31, 2022, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2022, based on criteria established in Internal Control - Integrated Framework (2013) issued by COSO.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated financial statements as of and for the year ended December 31, 2022, of the Company and our report dated March 8, 2023, expressed an unqualified opinion on those financial statements.

​

As described in Management’s Report to Shareholders, management excluded from its assessment the internal control over financial reporting at Leucrotta Exploration Inc., which was acquired on May 31, 2022, and whose financial statements constitute 8% of total assets and 2% of total revenues of the consolidated financial statement amounts as of and for the year ended December 31, 2022. Accordingly, our audit did not include the internal control over financial reporting at Leucrotta Exploration Inc.

​

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 to Shareholders. 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/ Deloitte LLP
Chartered Professional Accountants
Calgary, Canada
March 8, 2023

​

Vermilion Energy Inc.  ∎ Page 5 ∎  2022 Financial Statements

Report of Independent Registered Public Accounting Firm

To the Shareholders and the Board of Directors of Vermilion Energy Inc.

Opinion on the Financial Statements

We have audited the accompanying consolidated balance sheet of Vermilion Energy Inc. and subsidiaries (the "Company") as of December 31, 2022 and 2021, the related consolidated statements of net earnings and comprehensive income, consolidated statements of cash flows and consolidated statements of changes in shareholders' equity for each of the two years in the period ended December 31, 2022, and the related notes (collectively referred to as the "financial statements"). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2022 and 2021, and its financial performance and its cash flows for each of the two years in the period ended December 31, 2022, in conformity with International Financial Reporting Standards as issued by the International Accounting Standards Board.

​

We have also 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 of December 31, 2022, based on criteria established in Internal Control — Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated March 8, 2023, expressed an unqualified opinion on the Company's internal control over financial reporting.

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 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 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 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 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 financial statements that were communicated or required to be communicated to the audit committee and that (1) relate to accounts or disclosures that are material to the 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 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.

Valuation of capital assets acquired from Leucrotta Exploration Inc. - Refer to Notes 2 and 4 to the financial statements

Critical Audit Matter Description

​

The Company completed the acquisition of Leucrotta Exploration Inc. for $500 million on May 31, 2022. The Company accounted for the acquisition as a business combination, which required  that assets acquired, and liabilities assumed to be measured at fair value on the acquisition date. Accordingly, the purchase price was allocated to the assets acquired and liabilities assumed based on their respective fair values, including capital assets of $559 million. The fair value of capital assets is estimated based on the future after-tax cash flows of the underlying proved and probable oil, natural gas liquids and natural gas reserves. The Company engages an independent reservoir engineer to estimate oil and natural gas reserves using estimates, assumptions, and engineering data. The development of the Company’s reserves and the related future after-tax cash flows used to evaluate the fair value requires management to make significant estimates and assumptions related to future oil, natural gas liquids and natural gas prices, discount rate, reserves, and future operating and development costs.

​

Given the significant judgments made by management related to future oil, natural gas liquids and natural gas prices, discount rate, reserves, and future operating and development costs, these estimates and assumptions are subject to a high degree of estimation uncertainty. Auditing these estimates and assumptions required a high degree of auditor judgment in applying audit procedures and in evaluating the results of those procedures. This resulted in an increased extent of audit effort, including the involvement of fair value specialists.

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Vermilion Energy Inc.  ∎ Page 6 ∎  2022 Financial Statements

How the Critical Audit Matter Was Addressed in the Audit

​

Our audit procedures related to future oil, natural gas liquids and natural gas prices, discount rate, reserves and future operating and development costs used to determine the fair value of capital assets included the following, among others:

● Evaluated the effectiveness of the relevant controls, including those over the determination of the future oil, natural gas liquids and natural gas prices, discount rate, reserves, and future operating and development costs.
● Evaluated the Company’s independent reservoir engineer by:
--- ---
̊ Examining reports and assessing their scope of work and findings; and
--- ---
̊ Assessing the competence, capability, and objectivity by evaluating their relevant professional qualifications and experience.
--- ---
● Evaluated the reasonableness of reserves by testing the source financial information underlying the reserves and comparing the reserve volumes to historical production volumes.
--- ---
● Evaluated the reasonableness of future operating and development costs by testing the source financial information underlying the estimate as of December 31, 2022 and performing rollback procedures to May 31, 2022 to assess any significant changes in assumptions, comparing future operating and development costs to historical results, and evaluating whether they are consistent with evidence obtained in other areas of the audit.
--- ---
● With the assistance of fair value specialists:
--- ---
̊ Evaluated the future oil, natural gas liquids and natural gas prices by independently developing a reasonable range of forecasts based on reputable third-party forecasts and market data and comparing those to the future prices selected by management; and
--- ---
̊ Evaluated the reasonableness of the discount rate by testing the source information underlying the determination of the discount rate and developing a range of independent estimates and comparing to the discount rate determined by management.
--- ---

​

Capital asset impairment reversal   – Refer to Note 2 and 6 to the financial statements

Critical Audit Matter Description

​

The Company reviews all Cash Generating Units (“CGUs”) for indicators of potential impairment or reversal of impairment at each reporting date. As a result of increasing commodity price forecasts during the year, indicators of impairment reversal were identified for those CGUs where impairment loss was recognized in prior years. An impairment reversal is recognized if the carrying amount of the CGU is less than its recoverable amount. The recoverable amount of a CGU is estimated based on the higher of its fair value less cost of disposal and its value-in-use, using future after-tax cash flows of the underlying proved and probable oil and natural gas reserves. The Company engages an independent reservoir engineer to estimate oil and natural gas reserves using estimates, assumptions, and engineering data. The development of the Company’s reserves and the related future after-tax cash flows used to evaluate the impairment reversal requires management to make significant estimates and assumptions related to future oil, natural gas liquids and natural gas prices, discount rate, reserves, and future operating and development costs. Impairment reversals totaling $192 million were recorded for the year ended December 31, 2022.

​

Given the significant judgments made by management related to future oil, natural gas liquids and natural gas prices, discount rate, reserves, and future operating and development costs, these estimates and assumptions are subject to a high degree of estimation uncertainty. Auditing these estimates and assumptions are subject to a high degree of auditor judgment in applying audit procedures and in evaluation of the results of those procedures. This resulted in an increased extent of audit effort, including the involvement of fair value specialists.

​

How the Critical Audit Matter Was Addressed in the Audit

​

Our audit procedures related to future oil, natural gas liquids and natural gas prices, discount rate, reserves, and future operating and development costs used to determine the recoverable amount of the CGUs included the following, among others:

​

● Evaluate management’s assessment and independently assess petroleum natural gas assets for indicators of impairment or impairment reversal.
● Evaluated the effectiveness of the relevant controls, including those over the determination of the future oil, natural gas liquids and natural gas prices, discount rate, reserves, and future operating and development costs.
--- ---
● Evaluated the Company’s independent reservoir engineer by:
--- ---
̊ Examining reports and assessing their scope of work and findings; and
--- ---
̊ Assessing the competence, capability, and objectivity by evaluating their relevant professional qualifications and experience.
--- ---
● Evaluated the reasonableness of reserves by testing the source financial information underlying the reserves and comparing the reserve volumes to historical production volumes.
--- ---
● Evaluated the reasonableness of future operating and development costs by testing the source financial information underlying the estimate, comparing future operating and development costs to historical results, and evaluating whether they are consistent with evidence obtained in other areas of the audit.
--- ---

Vermilion Energy Inc.  ∎ Page 7 ∎  2022 Financial Statements

● With the assistance of fair value specialists:
̊ Evaluated the future oil, natural gas liquids and natural gas prices by independently developing a reasonable range of forecasts based on reputable third-party forecasts and market data and comparing those to the future prices selected by management; and
--- ---
̊ Evaluated the reasonableness of the discount rate by testing the source information underlying the determination of the discount rate and developing a range of independent estimates and comparing those to the discount rate determined by management.
--- ---

​

Valuation of deferred tax asset - Refer to Notes 2 and 11 to the financial statements

Critical Audit Matter Description

​

The Company recognizes deferred income taxes for differences between the financial statement and tax basis of assets and liabilities at substantively enacted statutory tax rates in effect for the years in which the differences are expected to reverse.

​

Deferred income tax assets are reduced to the amounts expected to be realized based on forecasts of future taxable income, specifically forecasts of future revenue (commodity price forecasts and forecasted reserves). The Company recorded a deferred income tax asset for Ireland primarily arising from past taxable losses in this jurisdiction.

​

To determine whether it is probable that the deferred income tax assets in Ireland will be realized, management makes assumptions related to the forecasts of future taxable income, specifically forecasts of future revenue (commodity price forecasts and forecasted reserves). As such, auditing the probability of the deferred income tax assets being realized and management’s commodity price forecasts and forecasted reserves involved a high degree of auditor judgement as the estimations made by management contain significant measurement uncertainty. This resulted in an increased extent of audit effort, which included the need to involve income tax specialists.

​

How the Critical Audit Matter Was Addressed in the Audit

​

Our audit procedures related to assessing the probability of the deferred income tax assets being realized and management’s forecasts of taxable income, specifically forecasts of future revenue (commodity price forecasts and forecasted reserves) to evaluate the deferred income tax assets in Ireland included the following, among others:

​

● Evaluated the effectiveness of relevant controls, including those over the determination of the forecasts of future revenue, specifically commodity price forecasts and forecasted reserves in Ireland.
● Evaluated management’s ability to accurately forecast future taxable income by comparing management’s assumptions to historical data and available market trends.
--- ---
● Evaluated the reasonableness of management's forecasts of future revenue by:
--- ---
̊ Comparing the forecasts prepared by management’s expert to third party forecasts; and,
--- ---
̊ Evaluating whether management’s estimates of commodity price forecasts and estimated reserves were consistent with the requirements of IAS 12 - Income taxes relating to the probability of forecasted future revenue and the length of the forecast period.
--- ---

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/s/ Deloitte LLP
Chartered Professional Accountants
Calgary, Canada
March 8, 2023

​

We have served as the Company’s auditor since 2000.

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Vermilion Energy Inc.  ∎ Page 8 ∎  2022 Financial Statements

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Consolidated Financial Statements

Consolidated Balance Sheet

thousands of Canadian dollars

​ ​ ​ ​ ​ ​ ​
​ Note December 31, 2022 December 31, 2021
Assets ​ ​ ​ ​ ​ ​
Current ​ ​ ​ ​ ​ ​
Cash and cash equivalents 19 13,836 6,028
Accounts receivable ​ 19 373,651 328,584
Crude oil inventory ​ 19 19,657 20,070
Derivative instruments 9 162,843 19,321
Prepaid expenses ​ 19 144,459 98,842
Total current assets ​ ​ 714,446 472,845
​ ​ ​ ​ ​ ​ ​
Derivative instruments 9 132,598 —
Investment in securities ​ 5 ​ 56,366 ​ —
Deferred taxes 11 125,533 374,993
Exploration and evaluation assets 4, 7 270,593 233,290
Capital assets 4, 6 5,691,522 4,824,195
Total assets ​ ​ 6,991,058 5,905,323
​ ​ ​ ​ ​ ​ ​
Liabilities ​ ​ ​ ​
Current ​ ​ ​ ​
Accounts payable and accrued liabilities ​ 19 481,444 440,658
Dividends payable 13 13,058 —
Derivative instruments 9 55,845 268,973
Income taxes payable ​ 19 341,698 37,182
Total current liabilities ​ ​ 892,045 746,813
​ ​ ​ ​ ​ ​ ​
Derivative instruments 9 — 51,213
Long-term debt 12 1,081,351 1,651,569
Lease obligations 10 51,507 60,190
Asset retirement obligations 8 1,087,757 1,000,554
Deferred taxes 11 477,340 328,839
Total liabilities ​ ​ 3,590,000 3,839,178
​ ​ ​ ​ ​ ​ ​
Shareholders' Equity ​ ​ ​ ​
Shareholders' capital 13 4,243,794 4,241,773
Contributed surplus ​ ​ 35,409 49,529
Accumulated other comprehensive income ​ ​ 123,505 28,467
Deficit ​ ​ (1,001,650) (2,253,624)
Total shareholders' equity ​ ​ 3,401,058 2,066,145
Total liabilities and shareholders' equity ​ ​ 6,991,058 5,905,323

​

Approved by the Board

​

(Signed “Robert Michaleski”) (Signed “Manjit Sharma”)
Robert Michaleski, Director Manjit Sharma, Director

​

​

Vermilion Energy Inc.  ∎ Page 9 ∎  2022 Financial Statements

Consolidated Statements of Net Earnings and Comprehensive Income

thousands of Canadian dollars, except share and per share amounts

​ ​ ​ ​ ​ ​ ​
​ ​ ​ ​ Year Ended
​ Note Dec 31, 2022 Dec 31, 2021
Revenue ​ ​ ​ ​ ​ ​
Petroleum and natural gas sales ​ ​ **** 3,476,394 2,079,761
Royalties ​ ​ **** (306,017) (186,122)
Sales of purchased commodities ​ ​ ​ 244,834 ​ 147,091
Petroleum and natural gas revenue ​ ​ **** 3,415,211 2,040,730
​ ​ ​ ​ ​
Expenses ​ ​ ​ ​
Purchased commodities ​ ​ ​ 244,834 ​ 147,091
Operating 19 **** 489,034 413,013
Transportation ​ ​ **** 78,896 77,161
Equity based compensation 15 **** 44,390 41,565
(Gain) loss on derivative instruments 9 **** (134,907) 508,478
Interest expense ​ ​ **** 82,858 73,075
General and administration 19 **** 57,677 52,877
Foreign exchange loss ​ ​ **** 69,269 71,576
Other income ​ ​ **** (11,149) (21,422)
Accretion 8 **** 58,170 43,552
Depletion and depreciation 6 **** 577,134 571,688
Impairment reversal ​ 6 ​ (192,094) ​ (1,302,619)
Gain on business combinations ​ **** — (17,198)
​ ​ ​ **** 1,364,112 658,837
Earnings before income taxes ​ ​ **** 2,051,099 1,381,893
​ ​ ​
Income tax expense ​
Deferred ​ 11 **** 288,707 187,343
Current ​ ​ **** 226,471 45,854
Windfall taxes ​ 11 ​ 222,859 ​ —
​ ​ ​ **** 738,037 233,197
​ ​ ​
Net earnings ​ ​ **** 1,313,062 1,148,696
​ ​ ​
Other comprehensive income ​ ​
Currency translation adjustments ​ ​ **** 60,543 (55,632)
Hedge accounting reserve ​ ​ ​ 5,599 ​ 6,113
Fair value adjustment on investment in securities, net of tax ​ 5 ​ 28,896 ​ —
Comprehensive income ​ ​ **** 1,408,100 1,099,177
​ ​ ​ ​ ​ ​ ​
Net earnings per share 16
Basic ​ ​ **** 8.03 7.13
Diluted ​ ​ **** 7.80 6.97
​ ​ ​ ​ ​
Weighted average shares outstanding ('000s) 16 ​ ​
Basic ​ ​ **** 163,489 161,172
Diluted ​ ​ **** 168,426 164,765

​

​

​

Vermilion Energy Inc.  ∎ Page 10 ∎  2022 Financial Statements

Consolidated Statements of Cash Flows

thousands of Canadian dollars

​ ​ ​ ​ ​ ​ ​
​ ​ ​ ​ Year Ended
​ Note Dec 31, 2022 Dec 31, 2021
Operating ​ ​ ​ ​ ​ ​
Net earnings ​ ​ 1,313,062 1,148,696
Adjustments: ​ ​ ​ ​
Accretion 8 58,170 43,552
Depletion and depreciation 6, 7 577,134 571,688
Impairment reversal ​ 6 ​ (192,094) ​ (1,302,619)
Gain on business combinations ​ — (17,198)
Unrealized (gain) loss on derivative instruments 9 (540,801) 181,094
Equity based compensation 15 44,390 41,565
Unrealized foreign exchange loss ​ ​ 84,464 64,963
Unrealized other expense ​ ​ 1,833 778
Deferred tax expense 11 288,707 187,343
Asset retirement obligations settled 8 (37,514) (28,525)
Changes in non-cash operating working capital 19 216,869 (56,884)
Cash flows from operating activities ​ ​ 1,814,220 834,453
​ ​ ​ ​ ​ ​ ​
Investing ​ ​ ​ ​
Drilling and development 6 (528,056) (339,390)
Exploration and evaluation 7 (23,761) (35,406)
Acquisitions, net of cash acquired 3, 5 (510,309) (131,628)
Acquisition of securities ​ 5 ​ (23,282) ​ —
Changes in non-cash investing working capital 19 26,116 36,724
Cash flows used in investing activities ​ ​ (1,059,292) (469,700)
​ ​ ​ ​ ​ ​ ​
Financing ​ ​ ****
Repayments on the revolving credit facility 12 (1,121,868) (341,259)
Issuance of senior unsecured notes 12 499,037 —
Payments on lease obligations 10 (21,168) (22,187)
Repurchase of shares ​ 13 ​ (71,659) ​ —
Cash dividends 13 (32,711) —
Cash flows used in financing activities ​ ​ (748,369) (363,446)
Foreign exchange gain (loss) on cash held in foreign currencies ​ ​ 1,249 (2,183)
​ ​ ​ ​ ​ ​ ​
Net change in cash and cash equivalents ​ ​ 7,808 (876)
Cash and cash equivalents, beginning of year ​ ​ 6,028 6,904
Cash and cash equivalents, end of year 19 13,836 6,028
​ ​ ​ ​ ​ ​ ​
Supplementary information for cash flows from operating activities ​ ​
Interest paid ​ ​ 75,042 71,369
Income taxes paid ​ ​ 144,814 13,212

​

​

​

Vermilion Energy Inc.  ∎ Page 11 ∎  2022 Financial Statements

Consolidated Statements of Changes in Shareholders’ Equity

thousands of Canadian dollars

​ ​ ​ ​ ​ ​ ​
​ ​ ​ ​ Year Ended
​ Note Dec 31, 2022 Dec 31, 2021
Shareholders' capital ​ 13 ​ ​ ​ ​
Balance, beginning of year **** ​ ​ 4,241,773 4,181,160
Vesting of equity based awards **** ​ ​ 44,811 49,922
Equity based compensation **** ​ ​ 13,699 8,365
Share-settled dividends on vested equity based awards **** ​ ​ 4,377 2,326
Repurchase of shares ​ ​ ​ (60,866) ​ —
Balance, end of year ​ ​ ​ 4,243,794 4,241,773
Contributed surplus 13 ​ ​ ​
Balance, beginning of year **** ​ ​ 49,529 66,250
Equity based compensation **** ​ ​ 30,691 33,201
Vesting of equity based awards **** ​ ​ (44,811) (49,922)
Balance, end of year **** ​ ​ 35,409 49,529
Accumulated other comprehensive income ​ ​ ​ ​
Balance, beginning of year **** ​ ​ 28,467 77,986
Currency translation adjustments **** ​ ​ 60,543 (55,632)
Hedge accounting reserve ​ ​ ​ 5,599 ​ 6,113
Fair value adjustment on investment in securities, net of tax ​ 5 ​ 28,896 ​ —
Balance, end of year **** ​ ​ 123,505 28,467
Deficit ​ ​
Balance, beginning of year **** ​ ​ (2,253,624) (3,399,994)
Net earnings **** ​ ​ 1,313,062 1,148,696
Dividends declared **** ​ ​ (45,769) —
Share-settled dividends on vested equity based awards **** ​ ​ (4,377) (2,326)
Repurchase of shares ​ 13 ​ (10,942) ​ —
Balance, end of year **** ​ ​ (1,001,650) (2,253,624)
Total shareholders' equity **** ​ ​ 3,401,058 2,066,145

​

​

Vermilion Energy Inc.  ∎ Page 12 ∎  2022 Financial Statements

Description of equity reserves

Shareholders’ capital

Represents the recognized amount for common shares issued (net of equity issuance costs and deferred taxes) less the weighted-average carrying value of shares repurchased. If the price paid to repurchase common shares is less than the carrying value of the shares repurchased, the difference is recorded to contributed surplus. If the price paid to repurchase common shares exceeds the carrying value of the shares repurchased, the difference is recorded as an increase to deficit.

Contributed surplus

Represents the recognized value of unvested equity based awards that will be settled in shares. Once vested, the value of the awards are transferred to shareholders’ capital.

Accumulated other comprehensive income

Represents currency translation adjustments, hedge accounting reserve and fair value adjustments on investments.

Currency translation adjustments result from translating the balance sheets of subsidiaries with a foreign functional currency to Canadian dollars at period-end rates. These amounts may be reclassified to net earnings if there is a disposal or partial disposal of a subsidiary.

The hedge accounting reserve represents the effective portion of the change in fair value related to cash flow and net investment hedges recognized in other comprehensive income, net of tax and reclassified to the consolidated statement of net earnings in the same period in which the transaction associated with the hedged item occurs. For the year ended December 31, 2022, accumulated losses of $4.3 million and $1.3 million were recognized in the consolidated statement of net earnings on the cash flow hedges and net investment hedges, respectively, and will be recognized in net earnings through 2025 when the senior unsecured notes mature.

Fair value adjustment on investment in securities, net of tax, are a result of changes in the fair value of investments that have been elected to be subsequently measured at fair value through other comprehensive income.

Deficit

Represents the cumulative net earnings less distributed earnings and surplus of the price paid to repurchase common shares of Vermilion Energy Inc. over the weighted-average carrying value of the shares repurchased.

​

Vermilion Energy Inc.  ∎ Page 13 ∎  2022 Financial Statements

Notes to the Consolidated Financial Statements for the year ended December 31, 2022 and 2021

tabular amounts in thousands of Canadian dollars, except share and per share amounts

1. Basis of presentation

​

Vermilion Energy Inc. and its subsidiaries (the “Company” or “Vermilion”) are engaged in the business of petroleum and natural gas exploration, development, acquisition, and production.

Vermilion was incorporated in Canada and the Company’s registered office and principal place of business is located at 3500, 520, 3rd Avenue SW, Calgary, Alberta, Canada.

These consolidated financial statements were approved and authorized for issuance by Vermilion’s Board of Directors on March 8, 2023.

​

  1. Significant accounting policies

Accounting framework

The consolidated financial statements are prepared in accordance with International Financial Reporting Standards (“IFRS”) as issued by the International Accounting Standards Board (“IASB”).

Principles of consolidation

The consolidated financial statements include the accounts of Vermilion Energy Inc. and its subsidiaries. Vermilion’s subsidiaries include entities in each of the jurisdictions that Vermilion operates as described in Note 3 (Segmented information) including: Canada, France, Netherlands, Germany, Ireland, Australia, the United States, and Central and Eastern Europe (Hungary, Slovakia, and Croatia). Vermilion Energy Inc. directly or indirectly through holding companies owns all of the voting securities of each material subsidiary. Transactions between Vermilion Energy Inc. and its subsidiaries have been eliminated.

Vermilion accounts for joint operations by recognizing the Company’s share of assets, liabilities, income, and expenses.

Exploration and evaluation assets

Vermilion classifies costs as exploration and evaluation (“E&E”) assets when they relate to exploring and evaluating an area for which the Company has the license or right to explore and extract resources. E&E costs may include: geological and geophysical costs; land and license acquisition costs; and costs for the drilling, completion, and testing of exploration wells.

E&E costs are reclassified to capital assets if the technical feasibility and commercial viability of the area can be determined. E&E assets are assessed for impairment prior to any reclassification. The technical feasibility and commercial viability of extracting the reserves is considered to be determinable when proved and probable reserves are identified.

Costs incurred prior to the acquisition of the legal rights to explore an area are expensed as incurred. If reserves are not found within the license area or the area is abandoned, the related E&E costs are depreciated over a period not greater than five years. If an exploration license expires prior to the commencement of exploration activities, the cost of the exploration license is written off through depreciation in the year of expiration.

Capital assets

Vermilion recognizes capital assets at cost less accumulated depletion, depreciation, and impairment losses. Costs include directly attributable costs incurred for the drilling, completion, and tie-in of wells and the construction of production and processing facilities.

When components of capital assets are replaced, disposed of, or no longer in use, they are derecognized. Gains and losses on disposal of capital assets are determined by comparing the proceeds of disposal compared to the carrying amount.

Depletion and depreciation

Capital assets are grouped into depletion units, which are groups of assets within a specific production area that have similar economic lives. Depletion units represent the lowest level of disaggregation for which costs are accumulated for the purposes of calculating depletion and depreciation.

The net carrying value of each depletion unit is depleted using the unit of production method by reference to the ratio of production in the period to the total proved and probable reserves, taking into account the future development costs necessary to bring the applicable reserves into production.

Vermilion Energy Inc.  ∎ Page 14 ∎  2022 Financial Statements

For the purposes of the depletion calculations, oil and gas reserves are converted to a common unit of measure on the basis of their relative energy content based on a conversion ratio of six thousand cubic feet of natural gas to one barrel of oil equivalent.

Impairment of capital assets and exploration and evaluation assets

Depletion units are aggregated into cash generating units (“CGUs”) for impairment testing. CGUs are the lowest level for which there are identifiable cash inflows that are largely independent of cash inflows of other groups of assets. CGUs are reviewed for indicators of potential impairment at each reporting date.

E&E assets are tested for impairment when reclassified to capital assets or when indicators of potential impairment are identified. E&E assets are reviewed for indicators of potential impairment at each reporting date. If indicators of potential impairment are identified, E&E assets are tested for impairment as part of the CGU attributable to the jurisdiction in which the exploration area resides.

If an indicator of potential impairment exists, the CGU’s carrying value is compared to its recoverable amount. A CGU’s recoverable amount is the higher of its fair value less costs of disposal and its value-in-use. If the carrying amount of a CGU exceeds its recoverable amount, an impairment loss is recognized to reduce the carrying value of the CGU to its recoverable amount.

If an impairment loss has been recognized in a prior period, an assessment is performed at each reporting date to determine if there are indicators that the circumstances which led to the impairment loss have reversed. If the change in circumstances results in the recoverable amount being higher than the carrying value after the impairment loss, then the impairment loss (net of depletion that would otherwise have been recorded) is reversed.

Lease obligations and right-of-use assets

A contract is, or contains, a lease if the contract conveys the right to control the use of an identified asset for a period of time in exchange for consideration. At the lease commencement date, a lease obligation is recognized at the present value of future lease payments, typically using the applicable incremental borrowing rate. A corresponding right-of-use asset is recognized at the amount of the lease obligation, adjusted for lease incentives received and initial direct costs. Vermilion does not recognize leases for short-term leases with a lease term of 12 months or less, or leases for low-value assets.

Payments are applied against the lease obligation and interest expense is recognized on the lease obligations using the effective interest rate method. Depreciation is recognized on the right-of-use asset over the lease term.

Cash and cash equivalents

Cash and cash equivalents include cash on deposit with financial institutions and guaranteed investment certificates.

Crude oil inventory

Crude oil inventory is valued at the lower of cost or net realizable value. The cost of crude oil inventory produced includes related operating expense, royalties, and depletion determined on a weighted-average basis.

Asset retirement obligations

Vermilion recognizes a provision for asset retirement obligations when an event occurs giving rise to an obligation of uncertain timing or amount. Asset retirement obligations are recognized on the consolidated balance sheet as a long-term liability with a corresponding increase to E&E or capital assets.

Asset retirement obligations reflect the present value of estimated future settlement costs. The discount rate used to calculate the present value is specific to the jurisdiction the obligation relates to and is reflective of current market assessment of the time value of money and risks specific to the liabilities that have not been reflected in the cash flow estimates.

Asset retirement obligations are remeasured at each reporting period to reflect changes in market rates and estimated future settlement costs. Asset retirement obligations are increased each reporting period to reflect the passage of time with a corresponding charge to accretion expense.

Revenue recognition

Revenue associated with the sale of crude oil and condensate, natural gas, and natural gas liquids is measured based on the consideration specified in contracts with customers.

Revenue from contracts with customers is recognized when or as Vermilion satisfies a performance obligation by transferring control of crude oil and condensate, natural gas, or natural gas liquids to a customer at contractually specified transfer points. This transfer coincides with title passing to the customer and the customer taking physical possession of the commodity. Vermilion principally satisfies its performance obligations at a point in time and the amounts of revenue recognized relating to performance obligations satisfied over time are not significant.

Vermilion Energy Inc.  ∎ Page 15 ∎  2022 Financial Statements

Vermilion invoices customers for delivered products monthly and payment occurs shortly thereafter. Vermilion does not have any contracts where the period between the transfer of control of the commodity to the customer and payment by the customer exceeds one year. As a result, Vermilion does not adjust its revenue transactions to reflect significant financing components.

Financial instruments

On initial recognition, financial instruments are measured at fair value. Measurement in subsequent periods depends on the classification of the financial instrument as described below:

● Fair value through profit or loss ("FVTPL"): Financial instruments under this classification include cash and cash equivalents and derivative assets and liabilities. Transaction costs under this classification are expensed as incurred.
● Fair value through other comprehensive income ("FVTOCI"): Financial instruments under this classification include derivative assets, investment in securities, and liabilities where hedge accounting is applied. Transaction costs under this classification are expensed as incurred.
--- ---
● Amortized cost: Financial instruments under this classification include accounts receivable, accounts payable and accrued liabilities, dividends payable, lease obligations, and long-term debt. Transaction costs under this classification are included in the measurement of the financial instrument.
--- ---

Accounts receivable are measured net of a loss allowance equal to the lifetime expected credit loss.

Hedge accounting

Hedge accounting is applied to financial instruments designated as hedging instruments in qualifying hedging relationships.  Qualifying hedge relationships may include cash flow hedges, fair value hedges, and hedges of net investments in foreign operations.  The purpose of hedge accounting is to represent the effect of Vermilion's risk management activities to manage exposures arising from specific risks that affect net earnings such as foreign currency risk.

In order to apply hedge accounting, the eligible hedging instrument must be highly effective in offsetting the exposure to changes in the eligible hedged item.  This effectiveness is assessed at inception and at the end of each reporting period thereafter.  At inception, formal designation and documentation of the hedging relationship, risk management objective and strategy is required for undertaking the hedge.

For cash flow and net investment hedges, gains and losses on the hedging instrument are recognized in the consolidated statement of earnings in the same period in which the transaction associated with the hedged item occurs.  Where the hedging instrument is a derivative instrument, a derivative asset or liability is recognized on the balance sheet at fair value (included in "Derivative instruments") with the effective portion of the gain or loss recorded to other comprehensive income.  Any gain or loss associated with the ineffective portion of the hedging relationship is recognized in the consolidated statement of net earnings as other income or expense.

If a hedging relationship no longer qualifies for hedge accounting, any gain or loss resulting from the discontinuation of hedge accounting is deferred in other comprehensive income until the forecasted transaction date.  If the forecasted transaction is no longer expected to occur, any gain or loss resulting from the discontinuation of hedge accounting is immediately recognized in the consolidated statement of net earnings.

Equity based compensation

Equity based compensation expense results from equity-settled awards issued under Vermilion’s long-term share-based compensation plans as well as the grant date fair value of Vermilion common shares issued under the Company’s bonus and employee share savings plans.

Vermilion’s long-term share-based compensation plans consist of the Long-term Incentive Plan (“LTIP”) and the Deferred Share Unit Plan ("DSU"). Equity-settled awards issued under the LTIP vest over a period of one to three years and awards issued under the DSU vest immediately upon granting.

Equity based compensation expense for equity-settled plans is recognized over the vesting period with a corresponding adjustment to contributed surplus. The expense recognized is based on the grant date fair value of the awards, an estimate of the performance factor that will be achieved (if applicable), and an estimate of forfeiture rates based on historical vesting data. Dividends notionally accrue to the LTIP and are excluded in the determination of grant date fair values. When the awards are converted to Vermilion common shares, the amount recognized in contributed surplus is reclassified to shareholders’ capital.

The grant date fair value of awards or Vermilion common shares issued is determined as the closing price of Vermilion’s common shares on the Toronto Stock Exchange on the grant date.

Vermilion Energy Inc.  ∎ Page 16 ∎  2022 Financial Statements

Per share amounts

Basic net earnings per share is calculated by dividing net earnings by the weighted-average number of shares outstanding during the period.

Diluted net earnings per share is calculated by dividing net earnings by the diluted weighted-average number of shares outstanding during the period. The diluted weighted-average number of shares outstanding is the sum of the basic weighted-average number of shares outstanding and (to the extent inclusion reduces diluted net earnings per share) the number of shares issuable for equity-settled awards determined using the treasury stock method. The treasury stock method assumes that the unrecognized equity based compensation expense are deemed proceeds used to repurchase Vermilion common shares at the average market price during the period.

Foreign currency translation

Vermilion Energy Inc.’s functional and presentation currency is the Canadian dollar. Vermilion has subsidiaries that transact and operate in countries other than Canada and have functional currencies other than the Canadian dollar.

Foreign currency translation includes the translation of foreign currency transactions and the translation of foreign operations.

Foreign currency transaction translation occurs when translating transactions and balances in foreign currencies to the applicable functional currency of Vermilion Energy Inc. and its subsidiaries. Gains and losses from foreign currency transactions are recorded as foreign exchange gains or losses in the statement of net earnings. Foreign currency transaction translation occurs as follows:

● Income and expenses are translated at the prevailing rates on the date of the transaction.
● Non-monetary assets or liabilities are carried at the prevailing rates on the date of the transaction.
--- ---
● Monetary items, including intercompany loans that are not deemed to represent net investments in a foreign subsidiary, are translated at the prevailing rates at the balance sheet date.
--- ---

Foreign operation translation occurs when translating the financial statements of non-Canadian functional currency subsidiaries to the Canadian dollar and when translating intercompany loans that are deemed to represent net investments in a foreign subsidiary. Gains and losses from foreign operation translations are recorded as currency translation adjustments in the statement of comprehensive income. Foreign operation translation occurs as follows:

● Income and expenses are translated at the average exchange rates for the period.
● Assets and liabilities are translated at the prevailing rates on the balance sheet date.
--- ---

Income taxes

Deferred tax assets and liabilities are calculated using the balance sheet method. Deferred tax assets and liabilities are recognized for the estimated effect of any temporary differences between the amounts recognized on Vermilion’s consolidated balance sheet and the respective tax basis. This calculation uses enacted or substantively enacted tax rates that are expected to be in effect when the temporary differences are expected to reverse. The effect of a change in tax rates on deferred taxes is recognized in the period the related legislation is substantively enacted.

Deferred tax assets are recognized to the extent that it is probable that future taxable profits will be available against which the deductible temporary differences can be used. Deferred tax assets are reviewed at each reporting date and are reduced to the extent it is no longer probable that the related tax benefit will be realized.

Business combinations

Acquisitions of corporations or groups of assets are accounted for as business combinations using the acquisition method if the acquired assets constitute a business. Under the acquisition method, assets acquired and liabilities assumed in a business combination (with the exception of deferred tax assets and liabilities) are measured at their fair values. Deferred tax assets or liabilities arising from the assets acquired and liabilities assumed are measured in accordance with the policies described in "Income taxes" above.

If applicable, the excess or deficiency of the fair value of net assets acquired compared to consideration paid is recognized as a gain on business combination or as goodwill on the consolidated balance sheet. Acquisition-related costs incurred to effect a business combination are expensed in the period incurred.

As part of the assessment to determine if the acquisition constitutes a business, Vermilion may elect to apply the concentration test on a transaction by transaction basis. The test is met if substantially all of the fair value related to the gross assets acquired is concentrated in a single identifiable asset (or group of similar assets) resulting in the acquisition not being deemed a business and recorded as an asset acquisition.

Vermilion Energy Inc.  ∎ Page 17 ∎  2022 Financial Statements

Segmented information

Vermilion has a decentralized business unit structure designed to manage assets in each country the Company operates. Each of Vermilion’s operating segments derives its revenues solely from the production and sale of petroleum and natural gas.

Vermilion’s Corporate segment aggregates costs incurred at the Company’s Corporate head office located in Calgary, Alberta, Canada as well as costs incurred relating to Vermilion’s exploration and production activities in Hungary, Slovakia, and Croatia (Central and Eastern Europe). These operating segments have similar economic characteristics as they do not currently generate material revenue.

Vermilion’s chief operating decision maker regularly reviews fund flows from operations generated by each of Vermilion’s operating segments. Fund flows from operations is a measure of profit or loss that provides the chief operating decision maker with the ability to assess the profitability of each operating segment and, correspondingly, the ability of each operating segment to fund its share of dividends, asset retirement obligations, and capital investments.

Management judgments and estimation uncertainty

The preparation of the consolidated financial statements in accordance with IFRS requires management to make judgments, estimates, and assumptions that affect the reported amount of assets, liabilities, income, and expenses. Actual results could differ significantly from these estimates. Key areas where management has made judgments, estimates, and assumptions are described below.

The determination of whether indicators of impairment or impairment reversals:

● Determining whether there are indicators of impairment or impairment reversals are based on management's assessments of the changes in estimates for future commodity prices, costs, discount rates, or reserves. Changes in these estimates and assumptions can directly impact the calculated fair value of capital assets and therefore could be indicators of impairment or impairment reversals. In addition, change in the Vermilion's market capitalization relative to its book value could be an indicator of impairment.

The measurement of the fair value of capital assets acquired in a business combination and the determination of the recoverable amount of cash generating units ("CGU"):

● Calculating the fair value of capital assets acquired in a business combination and the recoverable amount of CGUs (in the assessment of impairments or reversals of previous impairments if indicators of impairment or impairment reversal are identified) are based on estimated future commodity prices, discount rates and estimated reserves. Reserve estimates are based on: engineering data, estimated future commodity prices, expected future rates of production, and assumptions regarding the timing and amount of future expenditures. Changes in these estimates and assumptions can directly impact the calculated fair value of capital assets acquired (and thus the resulting goodwill or gain on business combination) and the recoverable amount of a CGU (and thus the resulting impairment loss or recovery).
● In addition, the recoverable amount of a CGU is impacted by the composition of CGUs, which are subject to management’s judgment of the lowest level at which there are identifiable cash inflows that are largely independent of the cash inflows of other groups of assets. The factors used by Vermilion to determine CGUs vary by jurisdiction due to their unique operating and geographic conditions. In general, Vermilion will assess the following factors: geographic proximity of the assets within a group to one another, geographic proximity of the group of assets to other groups of assets, homogeneity of the production from the group of assets and the sharing of infrastructure used to process and/or transport production. Changes in these judgments can directly impact the calculated recoverable amount of a CGU (and thus the resulting impairment loss or recovery).
--- ---

The measurement of the carrying value of asset retirement obligations on the balance sheet, including the fair value and subsequent carrying value of asset retirement obligations assumed in a business combination:

● Asset retirement obligations are based on judgments regarding regulatory requirements, estimates of future costs, assumptions on the expected timing of expenditures, and estimates of the underlying risk inherent to the obligation. The carrying balance of asset retirement obligations and accretion expense may differ due to changes in: laws and regulations, technology, the expected timing of expenditures, and market conditions affecting the discount rate applied.

The recognition and measurement of deferred tax assets and liabilities:

● Tax interpretations, regulations, and legislation in the various jurisdictions in which Vermilion and its subsidiaries operate are subject to change and interpretation. Changes in laws and interpretations can affect the timing of the reversal of temporary tax differences, the tax rates in effect when such differences reverse and Vermilion’s ability to use tax losses and other tax pools in the future. The Company’s income tax filings are subject to audit by taxation authorities in numerous jurisdictions and the results of such audits may increase or decrease the tax liability. The determination of tax amounts recognized in the consolidated financial statements are based on management’s assessment of the tax positions, which includes consideration of their technical merits, communications with tax authorities and management’s view of the most likely outcome.

Vermilion Energy Inc.  ∎ Page 18 ∎  2022 Financial Statements

● The extent to which deferred tax assets are recognized are based on estimates of future profitability. These estimates are based on estimated future commodity prices and estimates of reserves. Judgments, estimates, and assumptions inherent in reserve estimates are described above.

The measurement of lease obligations and corresponding right-of-use assets:

● The measurement of lease obligations are subject to management’s judgments of the applicable incremental borrowing rate and the expected lease term. The carrying balance of the right-of-use assets, lease obligations, and the resulting interest and depletion and depreciation expense, may differ due to changes in the market conditions and expected lease terms. Applicable incremental borrowing rates are based on judgments of the economic environment, term, currency, and the underlying risk inherent to the asset. Lease terms are based on assumptions regarding cancellation and extension terms that allow for operational flexibility based on future market conditions.

​

  1. Segmented information

​

Substantially all sales in the France and Netherlands operating segments for the years ended December 31, 2022 and December 31, 2021 were to one customer in each respective segment. In 2022 and 2021, France and the Netherlands each contributed more than 10% of Vermilion's consolidated revenues.

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Year Ended December 31, 2022
​ **** Canada ​ USA **** France **** Netherlands **** Germany **** Ireland **** Australia **** Corporate **** Total
Total assets 3,612,487 ​ 618,116 823,544 240,276 398,612 465,643 249,253 583,127 6,991,058
Drilling and development 275,203 ​ 63,353 44,250 21,629 25,087 3,030 95,173 331 528,056
Exploration and evaluation — ​ — 2 23 1,070 — — 22,666 23,761
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Crude oil and condensate sales 910,863 ​ 130,150 365,431 2,119 62,464 15 221,187 — 1,692,229
NGL sales 114,128 ​ 19,385 — — — — — — 133,513
Natural gas sales 319,293 ​ 16,698 — 560,738 418,796 324,330 — 10,797 1,650,652
Sales of purchased commodities ​ — ​ — ​ — ​ — ​ — ​ — ​ — ​ 244,834 ​ 244,834
Royalties (196,005) ​ (44,427) (40,353) (512) (21,232) — — (3,488) (306,017)
Revenue from external customers 1,148,279 ​ 121,806 325,078 562,345 460,028 324,345 221,187 252,143 3,415,211
Purchased commodities — ​ — — — — — — (244,834) (244,834)
Transportation (44,849) ​ (618) (20,100) — (9,751) (3,578) — — (78,896)
Operating (240,899) ​ (27,372) (57,588) (45,903) (41,523) (16,580) (57,478) (1,691) (489,034)
General and administration ​ (28,643) ​ (5,863) ​ (16,444) ​ (4,255) ​ (6,949) ​ 122 ​ (4,964) ​ 9,319 ​ (57,677)
PRRT — ​ — — — — — (18,318) — (18,318)
Corporate income taxes (10) ​ — (29,889) (150,647) (31,513) — 5,016 (1,110) (208,153)
Windfall taxes ​ — ​ — ​ — ​ — ​ — ​ — ​ — ​ (222,859) ​ (222,859)
Interest expense — ​ — — — — — — (82,858) (82,858)
Realized loss on derivative instruments — ​ — — — — — — (405,894) (405,894)
Realized foreign exchange gain — ​ — — — — — — 15,195 15,195
Realized other income — ​ — — — — — — 12,982 12,982
Fund flows from operations **** 833,878 ​ 87,953 **** 201,057 **** 361,540 **** 370,292 **** 304,309 **** 145,443 **** (669,607) **** 1,634,865

​

Vermilion Energy Inc.  ∎ Page 19 ∎  2022 Financial Statements

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ Year Ended December 31, 2021
​ Canada ​ USA France Netherlands Germany Ireland Australia Corporate Total
Total assets 3,100,322 ​ 545,296 771,707 227,779 422,030 427,362 217,852 192,975 5,905,323
Drilling and development 190,242 ​ 32,540 39,587 20,198 19,234 1,261 34,785 1,543 339,390
Exploration and evaluation — ​ — 121 6,839 1,073 — — 27,373 35,406
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Crude oil and condensate sales 625,053 ​ 80,208 279,263 2,640 32,607 23 143,014 — 1,162,808
NGL sales 86,932 ​ 17,723 — — — — — — 104,655
Natural gas sales 189,790 ​ 14,484 — 293,083 99,328 214,402 — 1,211 812,298
Sales of purchased commodities ​ — ​ — ​ — ​ — ​ — ​ — ​ — ​ 147,091 ​ 147,091
Royalties (113,651) ​ (30,747) (37,666) (873) (2,847) — — (338) (186,122)
Revenue from external customers 788,124 ​ 81,668 241,597 294,850 129,088 214,425 143,014 147,964 2,040,730
Purchased commodities ​ — ​ — — — — — — (147,091) (147,091)
Transportation (38,764) ​ (1,336) (26,497) — (6,359) (4,205) — — (77,161)
Operating (215,378) ​ (16,992) (52,147) (35,269) (27,149) (14,889) (50,748) (441) (413,013)
General and administration (18,380) ​ (4,563) ​ (10,954) ​ (1,243) ​ (5,257) ​ 9 ​ (3,457) ​ (9,032) ​ (52,877)
PRRT — ​ — — — — — (15,688) — (15,688)
Corporate income taxes — ​ — 9,120 (46,567) — — 5,759 1,522 (30,166)
Interest expense — ​ — — — — — — (73,075) (73,075)
Realized loss on derivative instruments — ​ — — — — — — (327,384) (327,384)
Realized foreign exchange loss — ​ — — — — — — (6,613) (6,613)
Realized other income — ​ — — — — — — 22,200 22,200
Fund flows from operations **** 515,602 ​ 58,777 **** 161,119 **** 211,771 **** 90,323 **** 195,340 **** 78,880 **** (391,950) **** 919,862

​

Reconciliation of fund flows from operations to net earnings:

​

​ ​ ​ ​ ​
​ ​ Year Ended
​ Dec 31, 2022 Dec 31, 2021
Fund flows from operations 1,634,865 919,862
Equity based compensation (44,390) (41,565)
Unrealized gain (loss) on derivative instruments 540,801 (181,094)
Unrealized foreign exchange (loss) gain (84,464) (64,963)
Accretion (58,170) (43,552)
Depletion and depreciation (577,134) (571,688)
Deferred tax expense (288,707) (187,343)
Gain on business combinations — 17,198
Impairment reversal ​ 192,094 ​ 1,302,619
Unrealized other expense (1,833) (778)
**** Net earnings **** 1,313,062 **** 1,148,696

​

​

4. Business combinations

​

Leucrotta Exploration Inc.

On May 31, 2022, Vermilion closed the acquisition of all outstanding common shares of Leucrotta Exploration Inc. (“Leucrotta”), a Canadian publicly listed, Montney-focused oil and natural gas exploration and development company. The primary asset acquired is the Mica property, comprised of 81,000 gross (77,000 net) contiguous acres of Montney mineral rights in the Peace River Arch straddling the Alberta and British Columbia borders.

Prior to May 31, 2022, Vermilion controlled 7,536,800 common shares of Leucrotta. On May 31, 2022, Vermilion transferred consideration and assumed ownership of all remaining outstanding common shares of Leucrotta. The acquisition was funded through Vermilion’s revolving credit facility.

The total consideration and the fair value of the assets acquired and liabilities assumed at the date of acquisition are detailed in the table below:

​

​ ​ ​
​ **** Consideration
Cash consideration paid 486,488
Fair value of previously held equity interest 13,039
Total consideration **** 499,527

​

Vermilion Energy Inc.  ∎ Page 20 ∎  2022 Financial Statements

​ ​ ​
​ **** Allocation of consideration
Cash acquired 2,659
Capital assets 559,094
Exploration and evaluation assets 43,227
Deferred tax liabilities (97,891)
Asset retirement obligations (1,440)
Derivative liability (339)
Acquired working capital deficiency (5,783)
Net assets acquired **** 499,527

​

The results of operations from the assets acquired and liabilities assumed have been included in Vermilion’s consolidated financial statements beginning May 31, 2022 and have contributed revenues of $55.7 million and net earnings of $17.1 million. Had the acquisition occurred on January 1, 2022, consolidated petroleum and natural gas revenue would have been $3,444.7 million and consolidated net earnings would have been $1,322.0 million for the year ended December 31, 2022.

​

5. Investment in securities

​

Vermilion holds investments in Coelacanth Energy Inc., a Montney-focused oil and natural gas exploration and development company listed on the TSX Venture exchange. Vermilion has acquired shares via a private placement concurrent with the closing of the purchase of Leucrotta and via open market purchases. Vermilion has made an optional election to subsequently measure the investment at fair value through other comprehensive income. The investment is classified as a level 1 instrument on the fair value hierarchy and therefore uses observable inputs when making fair value adjustments.

The total consideration paid and the fair value of the investment acquired are detailed in the table below:

​

​ ​ ​
​ **** Amount
Balance at January 1 **** —
Acquisition of securities **** 23,282
Fair value adjustment **** 33,084
Balance at December 31 **** 56,366

​

​

  1. Capital assets

​

The following table reconciles the change in Vermilion’s capital assets:

​

​ ​ ​ ​ ​
​ 2022 2021
Balance at January 1 4,824,195 3,107,104
Acquisitions 572,535 180,806
Additions 528,056 339,390
Increase in right-of-use assets 13,871 551
Transfers from exploration and evaluation assets 1,223 11,495
Impairment reversal ​ 192,094 ​ 1,302,619
Depletion and depreciation (546,381) (538,704)
Changes in asset retirement obligations 65,462 528,714
Foreign exchange 40,467 (107,780)
Balance at December 31 5,691,522 4,824,195
​ ​ ​
Cost 12,058,520 10,849,047
Accumulated depletion, depreciation, and impairment (6,366,998) (6,024,852)
Carrying amount at December 31, 2022 5,691,522 4,824,195

​

In the first quarter of 2022, indicators of impairment reversal were present in our Canada - Saskatchewan and France - Neocomian cash generating units ("CGUs") due to an increase and stabilization in forecast oil prices. As a result of the indicators of impairment reversal, the Company performed impairment reversal calculations on the identified CGUs and the recoverable amounts were determined using fair value less costs to sell, which considered future after-tax cash flows from proved plus probable reserves and an after-tax discount rate of 12.0%. Based on the results of the

Vermilion Energy Inc.  ∎ Page 21 ∎  2022 Financial Statements

impairment reversal calculations completed, recoverable amounts were determined to be greater than the carrying values of the CGUs tested and $144.4 million (net of $47.7 million deferred income tax expense) of impairment reversal was recorded. Inputs used in the measurement of capital assets are not based on observable market data and fall within level 3 of the fair value hierarchy.

The following benchmark price forecasts were used to calculate the recoverable amounts:

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ **** 2022 **** 2023 **** 2024 **** 2025 **** 2026 **** 2027 **** 2028 **** 2029 **** 2030 **** 2031 ^(2)^
Brent Crude ($ US/bbl) ^(1)^ ​ 100.50 ​ 89.50 ​ 79.64 ​ 81.23 ​ 82.86 ​ 84.51 ​ 86.21 ​ 87.94 ​ 89.69 ​ 91.48
WTI Crude ($ US/bbl) ^(1)^ ​ 95.00 ​ 85.00 ​ 75.64 ​ 77.15 ​ 78.70 ​ 80.27 ​ 81.88 ​ 83.52 ​ 85.19 ​ 86.89
Exchange rate (CAD/USD) ​ 0.80 ​ 0.80 ​ 0.80 ​ 0.80 ​ 0.80 ​ 0.80 ​ 0.80 ​ 0.80 ​ 0.80 ​ 0.80

​

^(1) The forecast benchmark prices listed are adjusted for quality differentials, heat content, transportation and marketing costs and other factors specific to the Company’s operations when determining recoverable amounts.^​

^(2) In 2032 and beyond, commodity price forecasts are inflated at a rate of^^2.0%^^per annum. In 2032 and beyond there is no escalation of exchange rates.^

The following are the results of tests completed, recoverable amounts, and sensitivity impacts which would decrease impairment reversals taken:

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Operating Segment **** CGU **** Impairment Reversal ^(1)^ **** Recoverable Amount ​ 1% increase in discount rate **** 5% decrease in pricing
Canada Saskatchewan 159,985 2,150,936 ​ — —
France Neocomian 32,109 166,818 ​ — —
Total **** ​ **** 192,094 **** 2,317,754 ​ — —

​

^(1) Impairment reversals are subject to the lower of the recoverable amount and the carrying value, which includes depletion and depreciation of the CGU had no impairment charges been previously taken.^​

​

Right-of-use assets

The following table discloses the carrying balance and depreciation charge relating to right-of-use assets by class of underlying asset as at and for the year ended December 31, 2022:

​

​ ​ ​ ​ ​ ​ ​ ​
​ As at Dec 31, 2022 ​ As at Dec 31, 2021
(M) Depreciation **** Balance **** Depreciation **** Balance
Office space 8,328 **** 31,199 8,921 38,216
Gas processing facilities 7,691 **** 13,415 7,691 20,504
Oil storage facilities 2,429 **** 8,970 2,644 11,480
Vehicles and equipment 4,716 **** 13,944 3,629 6,038
Total 23,164 **** 67,528 22,885 76,238

All values are in US Dollars.

​

​

  1. Exploration and evaluation assets

The following table reconciles the change in Vermilion’s exploration and evaluation assets:

​ ​ ​ ​ ​
​ 2022 2021
Balance at January 1 233,290 254,094
Acquisitions 43,227 —
Additions 23,761 35,406
Changes in asset retirement obligations 646 110
Transfers to capital assets (1,223) (11,495)
Depreciation (30,503) (35,549)
Foreign exchange 1,395 (9,276)
Balance at December 31 270,593 233,290
​ ​
Cost 476,571 408,494
Accumulated depreciation (205,978) (175,204)
Carrying amount at December 31 270,593 233,290

​

​

Vermilion Energy Inc.  ∎ Page 22 ∎  2022 Financial Statements

  1. Asset retirement obligations

The following table reconciles the change in Vermilion’s asset retirement obligations:

​ ​ ​ ​ ​
​ 2022 2021
Balance at January 1 1,000,554 467,737
Additional obligations recognized 5,184 28,655
Changes in estimated abandonment timing and costs 207,919 85,022
Obligations settled (37,514) (28,525)
Accretion 58,170 43,552
Changes in rates (145,555) 439,849
Foreign exchange (1,001) (35,736)
Balance at December 31 1,087,757 1,000,554

​

Vermilion calculated the present value of the obligations using a credit-adjusted risk-free rate, calculated using a credit spread of 4.5% as at December 31, 2022 (December 31, 2021 – 4.9%) added to risk-free rates based on long-term, risk-free government bonds. Vermilion’s credit spread is determined using the Company’s expected cost of borrowing at the end of the reporting period.

The country-specific risk-free rates used as inputs to discount the obligations were as follows:

​ ​ ​ ​ ​ ​
​ Dec 31, 2022 Dec 31, 2021 ****
Canada 3.3 % 1.8 %
United States ​ 4.1 % 1.9 %
France 3.4 % 0.8 %
Netherlands 2.7 % (0.3) %
Germany 2.5 % 0.1 %
Ireland 3.2 % 0.5 %
Australia 4.2 % 1.9 %

​

Vermilion has estimated the asset retirement obligations based on current cost estimates of $2.3 billion (2021 - $2.0 billion). Current cost estimates are inflated to the estimated time of abandonment using inflation rates of between 1.6% and 4.2% (2021 - between 1.1% and 3.1%), resulting in inflated cost estimates of $3.7 billion (2021 - $3.1 billion). These payments are expected to be made over the next 60 years, with the majority of the costs incurred in the first 40 years.

A 0.5% increase/decrease in the discount rate applied to asset retirement obligations would decrease/increase asset retirement obligations by approximately $64.8 million. A one-year increase/decrease in the expected timing of abandonment spend would decrease/increase asset retirement obligations by approximately $54.0 million.

​

Vermilion Energy Inc.  ∎ Page 23 ∎  2022 Financial Statements

  1. Derivative instruments

The following table reconciles the change in the fair value of Vermilion’s derivative instruments:

​

​ ​ ​ ​ ​
​ ​ Year Ended
Dec 31, 2022 Dec 31, 2021
Fair value of contracts, beginning of year (300,865) (119,772)
Reversal of opening contracts settled during the year 164,208 112,679
Assumed in acquisitions (339) —
Realized loss on contracts settled during the year (405,894) (327,384)
Unrealized gain (loss) during the year on contracts outstanding at the end of the year 376,593 (293,773)
Net receipt from counterparties on contract settlements during the year 405,893 327,385
Fair value of contracts, end of year 239,596 (300,865)
Comprised of:
Current derivative asset 162,843 19,321
Current derivative liability (55,845) (268,973)
Non-current derivative asset 132,598 —
Non-current derivative liability — (51,213)
Fair value of contracts, end of year 239,596 (300,865)

​

The (gain) loss on derivative instruments for 2022 and 2021 were comprised of the following:

​

​ ​ ​ ​ ​
​ ​ Year Ended
Dec 31, 2022 Dec 31, 2021
Realized loss on contracts settled during the year 405,894 327,384
Reversal of opening contracts settled during the year (164,208) (112,679)
Unrealized (gain) loss on contracts outstanding at the end of the year (376,593) 293,773
(Gain) loss on derivative instruments (134,907) 508,478

​

Vermilion executes derivative instruments where there is an underlying exposure to offset the position. Consistent with our accounting policy we do not match unrealized gains / losses on these contracts with the underlying exposure. Please refer to Note 19 (Supplemental information) for a listing of Vermilion's outstanding derivative instruments as at December 31, 2022.

​

  1. Leases

Vermilion had the following future commitments associated with its lease obligations:

​

​ ​ ​ ​
​ As at
(M) Dec 31, 2022 Dec 31, 2021
Less than 1 year 23,588 19,045
1 - 3 years 40,374 38,136
3 - 5 years 16,246 25,226
After 5 years 177 3,686
Total lease payments 80,385 86,093
Amounts representing interest (9,392) (10,871)
Present value of net lease payments 70,993 75,222
Current portion of lease obligations (19,486) (15,032)
Non-current portion of lease obligations 51,507 60,190
​ ​ ​ ​
Total cash outflow 25,422 ​ 27,368
Interest on lease liabilities 4,254 ​ 5,181

All values are in US Dollars.

​

​

Vermilion Energy Inc.  ∎ Page 24 ∎  2022 Financial Statements

  1. Taxes

The following table reconciles Vermilion’s deferred tax asset and liability:

​

​ ​ ​ ​ ​
​ ​ As at
​ Dec 31, 2022 Dec 31, 2021
Deferred tax assets: ​ ​ ​
Non-capital losses 200,781 ​ 477,903
Derivative contracts — ​ 74,043
Other 39 ​ 2,879
Stock based compensation — ​ 8,651
Asset retirement obligations 5,818 ​ 83,461
Capital assets (81,105) ​ (268,615)
Unrealized foreign exchange — ​ (3,329)
Deferred tax assets **** 125,533 ​ 374,993
Deferred tax liabilities: ​ ​ ​
Derivative contracts ​ 58,941 ​ —
Asset retirement obligations 100,670 ​ 104,258
Capital assets 734,146 ​ 322,641
Stock based compensation ​ (5,805) ​ —
Other (16,322) ​ (10,518)
Unrealized foreign exchange ​ (4,282) ​ —
Non-capital losses (390,008) ​ (87,542)
Deferred tax liabilities **** 477,340 ​ 328,839

​

Income tax expense differs from the amount that would have been expected if the reported earnings had been subject only to the statutory Canadian income tax rate as follows:

​

​ ​ ​ ​ ​ ​
​ ​ Year Ended
Dec 31, 2022 Dec 31, 2021
Earnings before income taxes 2,051,099 ​ 1,381,893
Canadian corporate tax rate 24.60 % 24.61 %
Expected tax expense 504,570 ​ 340,084 ​
Increase (decrease) in taxes resulting from: ​ ​ ​ ​
Petroleum resource rent tax rate (PRRT) differential ^(1)^ 13,729 ​ 27,281 ​
Foreign tax rate differentials ^(2) (3)^ 101,701 ​ 43,301 ​
Equity based compensation expense (11,610) ​ 6,794 ​
Amended returns and changes to estimated tax pools and tax positions (5,691) ​ (14,391) ​
Statutory rate changes and the estimated reversal rates on temporary differences ^(3)^ 14,274 ​ 5,862 ​
Derecognition (recognition) of deferred tax assets (118,304) ​ (190,423) ​
Windfall taxes ^(3)^ 222,859 — ​
Other non-deductible items 16,509 ​ 14,689 ​
Provision for income taxes 738,037 ​ 233,197 ​
(1) In Australia, current taxes include both corporate income tax rates and PRRT. For both 2022 and 2021, corporate income tax rates were applied at a rate of 30% and PRRT was applied at a rate of 40%.
--- ---
(2) The applicable tax rates for 2022 were: 25.8% in France, 50.0% in the Netherlands, 31.3% in Germany, 25.0% in Ireland, and 21.0% in the United States (2021: 27.4% in France, 50.0% in the Netherlands, 31.4% in Germany, 25.0% in Ireland, and 21.0% in the United States).
--- ---
(3) On December 28, 2019, the French Parliament approved the Finance Bill for 2020. The Finance Bill for 2020 provides for a progressive decrease of the French corporate income tax rate for companies with sales below €250 million from 32.0% to 25.8% by 2022. On December 21, 2021, the Dutch Senate approved the 2022 Tax Plan that included an increase to the Dutch corporate tax rate from 25.0% in 2021 to 25.8% in 2022. Due to the tax regime applicable to natural gas producers in the Netherlands, the increase to the corporate tax rate is not expected to have a material impact to Vermilion taxes in the Netherlands. On September 30, 2022 the Council of the European Union agreed, by way of regulation, to the implementation of a temporary windfall tax on the profits of oil and gas producers resident in the European Union. This windfall tax is referred to as a temporary solidarity contribution and is calculated on the amount by which the taxable profits for the elected years exceeds the greater of zero and 120% of the average taxable profits for the 2018 to 2021 period. The regulation requires Member States to implement the temporary solidarity contribution at a minimum rate of 33% while providing Member States with the option to apply the temporary solidarity contribution to fiscal years beginning on or after January 1, 2022, January 1, 2023, or both. The temporary solidarity contribution is considered a tax pursuant to IAS 12 “Income Taxes”. The related legislation became substantively enacted during the fourth quarter of 2022 resulting in a full year of windfall taxes being recognized during the fourth quarter.
--- ---

Vermilion Energy Inc.  ∎ Page 25 ∎  2022 Financial Statements

The following table summarizes the manner of implementation of the temporary solidarity contribution by the Member States in which Vermilion operates:

​ ​ ​ ​ ​ ​
Jurisdiction **** 2023 **** 2022 ​
France N/A ​ 33.0 %
Netherlands ^(1)^ N/A ​ 33.0 %
Germany 33.0 % 33.0 %
Ireland ^(2)^ N/A ​ N/A ​
(1) For 2023 and 2024, Netherlands has implemented a windfall royalty. This royalty applies if annual realized pricing (net of hedges) exceeds €0.50/Nm3. This royalty is assessed annually at a rate of 65% on realized pricing (net of hedges) less €0.50/Nm3 and payments on this royalty are deductible in calculating current income taxes.
--- ---
(2) As at December 31, 2022, Ireland has not legislated a windfall tax rate. A rate of 75% was announced in November 2022.
--- ---

At December 31, 2022, Vermilion had $2.4 billion (2021 - $2.7 billion) of unused tax losses of which $1.4 billion (2021 - $1.4 billion) relates to Vermilion's Canada segment and expire between 2025 and 2042. The majority of the remaining unused tax losses relate to Vermilion's Ireland segment and do not expire.

At December 31, 2022, Vermilion recognized $118.3 million (2021 - recognized $190.4 million) of deferred income tax assets primarily relating to the aforementioned non-expiring tax loss in Ireland that are expected to be utilized due to an increase in forecasted commodity prices.

The aggregate amount of temporary differences associated with investments in subsidiaries for which deferred tax liabilities have not been recognized as at December 31, 2022 is approximately $0.7 billion (2021 – approximately $0.4 billion).

​

  1. Long-term debt

The following table summarizes Vermilion’s outstanding long-term debt:

​

​ ​ ​ ​ ​
​ ​ As at
​ Dec 31, 2022 Dec 31, 2021
Revolving credit facility 147,666 1,273,755
2025 senior unsecured notes 404,463 377,814
2030 senior unsecured notes ​ 529,222 ​ —
Long-term debt 1,081,351 1,651,569

​

The fair value of the revolving credit facility is equal to its carrying value due to the use of short-term borrowing instruments at market rates of interest. The fair value of the 2025 senior unsecured notes as at December 31, 2022 was $391.3 million (December 31, 2021 - $387.0 million). The fair value of the 2030 senior unsecured notes as at December 31, 2022 was $496.8 million (December 31, 2021 - nil).

Vermilion Energy Inc.  ∎ Page 26 ∎  2022 Financial Statements

The following table reconciles the change in Vermilion’s long-term debt:

​

​ ​ ​ ​ ​
2022 2021
Balance at January 1 1,651,569 ​ 1,933,848
Repayments on the revolving credit facility (1,121,868) ​ (341,259)
Issuance of 2030 senior unsecured notes 499,037 —
Amortization of transaction costs 1,833 778
Foreign exchange 50,780 58,202
Balance at December 31 1,081,351 1,651,569

​

Revolving credit facility

As at December 31, 2022, Vermilion had in place a bank revolving credit facility maturing May 29, 2026 with the following terms:

​ ​ ​ ​ ​
​ ​ As at
​ Dec 31, 2022 Dec 31, 2021
Total facility amount 1,600,000 2,100,000
Amount drawn (147,666) (1,273,755)
Letters of credit outstanding (13,527) (11,035)
Unutilized capacity 1,438,807 815,210

​

The facility can be extended from time to time at the option of the lenders and upon notice from Vermilion. If no extension is granted by the lenders, the amounts owing pursuant to the facility are due at the maturity date. The facility is secured by various fixed and floating charges against the subsidiaries of Vermilion. On April 26, 2022, contemporaneous with the issuance of the 2030 senior unsecured notes and at Vermilion's election, the maturity date of the facility was extended to May 29, 2026 (previously May 31, 2024) and the total facility amount was reduced to $1.6 billion (previously $2.1 billion).

The facility bears interest at a rate applicable to demand loans plus applicable margins.

As at December 31, 2022, the revolving credit facility was subject to the following financial covenants:

​

​ ​ ​ ​ ​ ​ ​
​ ​ ​ ​ As at
Financial covenant Limit Dec 31, 2022 Dec 31, 2021
Consolidated total debt to consolidated EBITDA Less than 4.0 0.51 1.61
Consolidated total senior debt to consolidated EBITDA Less than 3.5 0.07 1.24
Consolidated EBITDA to consolidated interest expense Greater than 2.5 ​ 27.10 ​ 14.78

​

The financial covenants include financial measures defined within the revolving credit facility agreement that are not defined under IFRS. These financial measures are defined by the revolving credit facility agreement as follows:

● Consolidated total debt: Includes all amounts classified as “Long-term debt” and “Lease obligations” (including the current portion included within “Accounts payable and accrued liabilities” but excluding operating leases as defined under IAS 17) on the consolidated balance sheet.
● Consolidated total senior debt: Consolidated total debt excluding unsecured and subordinated debt.
--- ---
● Consolidated EBITDA: Consolidated net earnings before interest, income taxes, depreciation, accretion and certain other non-cash items, adjusted for the impact of the acquisition of a material subsidiary.
--- ---
● Consolidated total interest expense: Includes all amounts classified as “Interest expense”, but excludes interest on operating leases as defined under IAS 17.
--- ---

In addition, our revolving credit facility has provisions relating to our liability management ratings in Alberta and Saskatchewan whereby if our security adjusted liability management ratings fall below specified limits in a province, a portion of the asset retirement obligations are included in the definitions of consolidated total debt and consolidated total senior debt. An event of default occurs if our security adjusted liability management ratings breach additional lower limits for a period greater than 90 days. As of December 31, 2022, Vermilion’s liability management ratings were higher than the specified levels, and as such, no amounts relating to asset retirement obligations were included in the calculation of consolidated total debt and consolidated total senior debt.

As at December 31, 2022 and December 31, 2021, Vermilion was in compliance with the above covenants.

Vermilion Energy Inc.  ∎ Page 27 ∎  2022 Financial Statements

2025 senior unsecured notes

On March 13, 2017, Vermilion issued US $300.0 million of senior unsecured notes at par. The notes bear interest at a rate of 5.625% per annum, to be paid semi-annually on March 15 and September 15. The notes mature on March 15, 2025. As direct senior unsecured obligations of Vermilion, the notes rank equally with existing and future senior unsecured indebtedness of the Company.

The senior unsecured notes were recognized at amortized cost and include the transaction costs directly related to the issuance.

Vermilion may redeem some or all of the senior unsecured notes at the redemption prices set forth in the following table plus any accrued and unpaid interest, if redeemed during the twelve-month period beginning on March 15 of each of the years indicated below:

​

​ ​ ​ ​
Year Redemption price ****
2022 101.406 %
2023 and thereafter 100.000 %

​

2030 senior unsecured notes

On April 26, 2022, Vermilion closed a private offering of US $400.0 million 8-year senior unsecured notes. The notes were priced at 99.241% of par, mature on May 1, 2030, and bear interest at a rate of 6.875% per annum. Interest is paid semi-annually on May 1 and November 1, commencing on November 1, 2022. The notes are senior unsecured obligations of Vermilion and rank equally with existing and future senior unsecured indebtedness.

The senior unsecured notes were recognized at amortized cost and include the transaction costs directly related to the issuance.

Vermilion may, at its option, redeem the notes prior to maturity as follows:

​

● On or after May 1, 2025, Vermilion may redeem some or all of the senior unsecured notes at the redemption prices set forth below, together with accrued and unpaid interest.
● Prior to May 1, 2025, Vermilion may redeem up to 35% of the original principal amount of the notes with an amount of cash not greater than the net cash proceeds of certain equity offerings at a redemption price of 106.875% of the principal amount of the notes, together with accrued and unpaid interest.
--- ---
● Prior to May 1, 2025, Vermilion may also redeem some or all of the notes at a price equal to 100% of the principal amount of the notes, plus a “make-whole premium,” together with applicable premium, accrued and unpaid interest.
--- ---

​

​ ​ ​ ​
Year **** Redemption price ****
2025 103.438 %
2026 102.292 %
2027 101.146 %
2028 and thereafter 100.000 %

​

​

​

​

​

  1. Shareholders’ capital

The following table reconciles the change in Vermilion’s shareholders’ capital:

​

​ ​ ​ ​ ​ ​ ​ ​
​ ​ 2022 2021
Shareholders’ capital Shares (‘000s) Amount (M) Shares (‘000s) Amount ($M)
Balance at January 1 ​ 162,261 ​ 4,241,773 158,724 ​ 4,181,160
Vesting of equity based awards 2,578 ​ 44,811 2,385 ​ 49,922
Shares issued for equity based compensation 549 ​ 13,699 911 ​ 8,365
Share-settled dividends on vested equity based awards 178 ​ 4,377 241 ​ 2,326
Repurchase of shares (2,339) ​ (60,866) — ​ —
Balance at December 31 163,227 ​ 4,243,794 162,261 ​ 4,241,773

All values are in US Dollars.

​

Vermilion is authorized to issue an unlimited number of common shares with no par value.

Dividends declared to shareholders for the year ended December 31, 2022 were $45.8 million or $0.28 per common share (2021 - nil).

Subsequent to December 31, 2022 Vermilion declared a dividend of $0.10 per share to be paid April 17, 2023.

Vermilion Energy Inc.  ∎ Page 28 ∎  2022 Financial Statements

On July 4, 2022, the Toronto Stock Exchange approved our notice of intention to commence a normal course issuer bid ("the NCIB"). The NCIB allows Vermilion to purchase up to 16,076,666 common shares representing approximately 10% of its public float as at June 22, 2022 beginning July 6, 2022 and ending July 5, 2023.

In 2022, Vermilion purchased and cancelled 2.34 million common shares under the NCIB for total consideration of $71.7 million. The surplus between the total consideration and the carrying value of the shares repurchased was recorded as an increase to deficit.

Subsequent to December 31, 2022 Vermilion purchased and cancelled 1.14 million common shares under the NCIB for total consideration of $22.4 million.

​

  1. Capital disclosures

Vermilion defines capital as net debt (long-term debt (excluding unrealized foreign exchange on swapped USD borrowings) plus adjusted working capital (defined as current assets less current liabilities, excluding current derivatives and current lease liabilities)) and shareholders’ capital. In managing capital, Vermilion reviews whether fund flows from operations is sufficient to fund capital expenditures, dividends, and asset retirement obligations.

Vermilion monitors the ratio of net debt to fund flows from operations. As at December 31, 2022, our ratio of net debt to trailing fund flows from operations is 0.82 (2021 – 1.79). Vermilion manages the ratio of net debt to fund flows from operations (refer to Note 3 – Segmented information) by monitoring capital expenditures, dividends, and asset retirement obligations with expected fund flows from operations. Vermilion intends for the ratio of net debt to fund flows from operations to trend towards 1.0 over time.

The following table calculates Vermilion’s ratio of net debt to fund flows from operations:

​

​ ​ ​ ​ ​
​ ​ Year Ended
​ ​ ​ ​ ​
Dec 31, 2022 Dec 31, 2021
Long-term debt 1,081,351 1,651,569
Adjusted working capital ^(1)^ ​ 265,111 ​ 9,284
Unrealized FX on swapped USD borrowings ​ (1,876) ​ (16,067)
Net debt 1,344,586 1,644,786
​ ​ ​
Ratio of net debt to four quarter trailing fund flows from operations 0.82 1.79
^(1)^ Adjusted working capital is defined as current assets (excluding current derivatives), less current liabilities (excluding current derivatives and current lease liabilities).
--- ---

​

  1. Equity based compensation

The following table summarizes the number of awards outstanding under the LTIP:

​

​ ​ ​ ​ ​
Number of LTIP and Five Year Compensation Awards (‘000s) 2022 2021
Opening balance 6,405 6,244
Granted 1,108 2,745
Vested (1,733) (1,520)
Forfeited (277) (1,064)
Closing balance 5,503 6,405

​

For the year ended December 31, 2022, the awards had a weighted average grant date fair value of $25.60 (2021 - $9.53). Equity based compensation expense for the awards is calculated based on the number of awards outstanding multiplied by the estimated performance factor that will be realized upon vesting (2022 – 1.0; 2021 – 1.1) adjusted by an estimated annual forfeiture rate (2022 – 3.8%; 2021 – 4.2%). Equity based compensation expense of $29.2 million was recorded during the year ended December 31, 2022 (2021 - $31.3 million) relating to the awards.

As at December 31, 2022, there were 392,757 DSUs outstanding with a weighted average grant date fair value of $12.89. In 2022, there were 56,262 DSU grants with a weighted average grant date fair value of $26.70. Equity based compensation expense of $1.5 million was recorded during the year ended December 31, 2022 (2021 - $1.9 million) relating to the DSUs.

​

Vermilion Energy Inc.  ∎ Page 29 ∎  2022 Financial Statements

  1. Per share amounts

Basic and diluted net earnings per share have been determined based on the following:

​

​ ​ ​ ​ ​
​ ​ Year Ended
​ Dec 31, 2022 Dec 31, 2021
Net earnings 1,313,062 1,148,696
​ ​ ​ ​ ​
Basic weighted average shares outstanding (‘000s) 163,489 161,172
Dilutive impact of equity based compensation (‘000s) 4,937 3,593
Diluted weighted average shares outstanding (‘000s) 168,426 164,765
​ ​ ​
Basic earnings per share 8.03 7.13
Diluted earnings per share 7.80 6.97

​

​

  1. Financial instruments

Classification of financial instruments

The following table summarizes the carrying value relating to Vermilion’s financial instruments:

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ As at Dec 31, 2022 ​ As at Dec 31, 2021
​ ​ ​ ​ ​ Amortized ​ ​ ​ ​ ​ ​ ​ Amortized ​ ​
(M) FVTPL FVTOCI Cost Total FVTPL FVTOCI Cost Total
Cash and cash equivalents 13,836 ​ — **** — ​ 13,836 6,028 ​ — — ​ 6,028
Derivative assets 295,441 ​ — **** — ​ 295,441 19,321 ​ — — ​ 19,321
Investment in securities — ​ 56,366 **** — ​ 56,366 — ​ — — ​ —
Derivative liabilities (55,845) ​ — ​ — ​ (55,845) (320,186) ​ — ​ — ​ (320,186)
Accounts receivable — ​ — **** 373,651 ​ 373,651 — ​ — 328,584 ​ 328,584
Accounts payable and accrued liabilities — ​ — **** (481,444) ​ (481,444) — ​ — (440,658) ​ (440,658)
Dividends payable — ​ — **** (13,058) ​ (13,058) — ​ — — ​ —
Lease obligations — ​ — ​ (51,507) ​ (51,507) ​ — ​ — ​ (60,190) ​ (60,190)
Long-term debt (1) — ​ — **** (1,081,351) ​ (1,081,351) — ​ — (1,651,569) ​ (1,651,569)

All values are in US Dollars.

​

(1) The carrying value of the above equals fair value except for long-term debt. The fair value of long-term debt was $1,035,671 (2021 - $1,660,778).

The carrying value of accounts receivable, accounts payable and accrued liabilities, dividends payable and lease obligations are a reasonable approximation of their fair value due to the short maturity of these financial instruments.  The carrying value of long-term debt outstanding on the revolving credit facility approximates its fair value due to the use of short-term borrowing instruments at market rates of interest.

Fair value measurements are categorized into a fair value hierarchy based on the lowest level input that is significant to the fair value measurement:

● Level 1 inputs are determined by reference to unadjusted quoted prices in active markets for identical assets or liabilities. Inputs used in fair value measurement of cash and cash equivalents , investment in securities, the revolving credit facility, and the senior unsecured notes are categorized as Level 1.
● Level 2 inputs are determined based on inputs other than unadjusted quoted prices that are observable, either directly or indirectly. The fair value of Vermilion’s derivative assets and liabilities are determined using pricing models that incorporate future price forecasts (supported by prices from observable market transactions) and credit risk adjustments.
--- ---
● Level 3 inputs are not based on observable market data. Vermilion does not have any financial instruments classified as Level  3.
--- ---

There were no transfers between levels in the hierarchy in the years ended December 31, 2022 and 2021.

Nature and Extent of Risks Associated with Financial Instruments

Vermilion is exposed to financial risks from its financial instruments. These financial risks include: market risk (includes commodity price risk, interest rate risk, and currency risk), credit risk, and liquidity risk.

Vermilion Energy Inc.  ∎ Page 30 ∎  2022 Financial Statements

Commodity price risk

Vermilion is exposed to commodity price risk on its derivative assets and liabilities which are used as part of the Company’s risk management program to mitigate the effects of changes in commodity prices on future cash flows. While transactions of this nature relate to future petroleum and natural gas production, Vermilion does not designate these derivative assets and liabilities as accounting hedges. As such, changes in commodity prices impact the fair value of derivative instruments and the corresponding gains or losses recognized on derivative instruments.

Currency risk

Vermilion is exposed to currency risk on its financial instruments denominated in foreign currencies. These financial instruments include cash and cash equivalents, accounts receivables, accounts payables, lease obligations, long-term debt, derivative assets and derivative liabilities. These financial instruments are primarily denominated in the US dollar and the Euro. Vermilion monitors its exposure to currency risk and reviews whether the use of derivative financial instruments is appropriate to manage potential fluctuations in foreign exchange rates.

Interest rate risk

Vermilion is exposed to interest rate risk on its revolving credit facility, which consists of short-term borrowing instruments that bear interest at market rates. Thus, changes in interest rates could result in an increase or decrease in the amount paid by Vermilion to service this debt.

The following table summarizes the increase (positive values) or decrease (negative values) to net earnings before tax due to a change in the value of Vermilion’s financial instruments as a result of a change in the relevant market risk variable. This analysis does not attempt to reflect any interdependencies between the relevant risk variables.

​

​ ​ ​ ​
(M) Dec 31, 2022 Dec 31, 2021
Currency risk - Euro to Canadian dollar
0.01 increase in strength of the Canadian dollar against the Euro 5,640 (273)
0.01 decrease in strength of the Canadian dollar against the Euro (5,640) 273
​ ​ ​ ​
Currency risk - US dollar to Canadian dollar ​ ​
0.01 increase in strength of the Canadian dollar against the US 5,441 2,086
0.01 decrease in strength of the Canadian dollar against the US (5,441) (2,086)
​ ​ ​ ​
Commodity price risk - Crude oil ​ ​
US 5.00/bbl increase in crude oil price used to determine the fair value of derivatives — (9,324)
US 5.00/bbl decrease in crude oil price used to determine the fair value of derivatives — 1,636
​ ​ ​ ​
Commodity price risk - European natural gas ​ ​
5.0/GJ increase in European natural gas price used to determine the fair value of derivatives (88,524) (10,554)
5.0/GJ decrease in European natural gas price used to determine the fair value of derivatives 91,828 10,554
​ ​ ​ ​
Share price risk - Equity swaps ​ ​ ​
1.00 increase from initial share price of the equity swap 3,750 ​ 3,750
1.00 decrease from initial share price of the equity swap (3,750) (3,750)

All values are in US Dollars.

​

Credit risk

Vermilion is exposed to credit risk on accounts receivable and derivative assets in the event that customers, joint operation partners, or counterparties fail to discharge their contractual obligations. As at December 31, 2022, Vermilion’s maximum exposure to receivable credit risk was $669.1 million (December 31, 2021 - $347.9 million) which is the value of accounts receivable and derivative assets on the balance sheet.

Vermilion’s accounts receivable primarily relates to customers and joint operations partners in the petroleum and natural gas industry. These amounts are subject to normal industry payment terms and credit risks. Vermilion manages these risks by monitoring the creditworthiness of customers and joint operations partners and, where appropriate, obtaining assurances such as parental guarantees and letters of credit. Vermilion determines the lifetime expected credit losses recognized on accounts receivable using a provision matrix. In preparing the provision matrix, the Company takes into account historical credit loss experience based on the aging of accounts receivable, adjusted as necessary for current and future petroleum and natural gas prices to the extent that changes in pricing may negatively impact the Company’s customers and joint operations partners. The lifetime expected credit losses on accounts receivable as at December 31, 2022 and 2021 is not material. As at the balance sheet date, approximately 0.5% (2021 –0.8%) of the accounts receivable balance was outstanding for more than 90 days. Vermilion considers the balance of accounts receivable to be collectible.

Vermilion Energy Inc.  ∎ Page 31 ∎  2022 Financial Statements

Vermilion’s derivative assets primarily relates to the fair value of financial instruments used as part of the Company’s risk management program to mitigate the effects of changes in commodity prices on future cash flows. Vermilion manages this risk by monitoring the creditworthiness of counterparties, transacting primarily with counterparties that have investment grade third party credit ratings, and by limiting the concentration of financial exposure to individual counterparties. As a result, Vermilion has not obtained collateral or other security to support its financial derivatives.

Vermilion’s cash deposited in financial institutions and guaranteed investment certificates are also subject to counterparty credit risk. Vermilion mitigates this risk by transacting with financial institutions with high third party credit ratings.

Liquidity risk

Liquidity risk is the risk that Vermilion will encounter difficulty in meeting obligations associated with its financial liabilities. Vermilion does not consider this to be a significant risk as its financial position and available committed borrowing facility provide significant financial flexibility and allow Vermilion to meet its obligations as they come due.

The following table summarizes Vermilion’s undiscounted non-derivative financial liabilities and their contractual maturities:

​

​ ​ ​ ​ ​ ​ ​ ​ ​
​ ​ 1 month to 3 months to 1 year to
($M) ​ 1 month ​ 3 months ​ 1 year ​ 5 years
December 31, 2022 192,572 278,520 23,412 607,796
December 31, 2021 191,297 223,885 25,475 1,718,475

​

​

  1. Related party disclosures

The compensation of directors and management is reviewed annually by the independent Governance and Human Resources Committee against industry practices for oil and gas companies of similar size and scope.

The following table summarizes the compensation of directors and other members of key management personnel during the years ended December 31, 2022 and 2021:

​

​ ​ ​ ​ ​
​ ​ Year Ended
​ Dec 31, 2022 Dec 31, 2021
Short-term benefits 5,124 4,654
Equity based compensation 8,951 ​ 14,570
​ 14,075 ​ 19,224
Number of individuals included in the above amounts 16 ​ 18

​

During the year ended December 31, 2022, Vermilion recorded $0.1 million of office rent recoveries (2021 - $0.2 million) relating to an office sub-lease to a company whose Managing Director was also a member of Vermilion’s Board of Directors during the year, but is no longer as at December 31, 2022. This related party transaction is provided in the normal course of business under the same commercial terms and conditions as transactions with unrelated companies and is recorded at the exchange amount.

​

Vermilion Energy Inc.  ∎ Page 32 ∎  2022 Financial Statements

  1. Supplemental information

Changes in non-cash working capital was comprised of the following:

​

​ ​ ​ ​ ​
​ ​ Year Ended
Dec 31, 2022 Dec 31, 2021
Changes in:
Accounts receivable (45,067) (132,507)
Crude oil inventory 413 (6,668)
Prepaid expenses (45,617) (71,156)
Accounts payable and accrued liabilities 40,786 142,988
Income taxes payable 304,516 32,643
Foreign exchange (12,046) 14,540
Changes in non-cash working capital 242,985 (20,160)
​ ​ ​ ​ ​
Changes in non-cash operating working capital 216,869 (56,884)
Changes in non-cash investing working capital 26,116 36,724
Changes in non-cash working capital 242,985 (20,160)

​

As at December 31, 2022, prepaid expenses includes a deposit of $68.5 million related to a previously announced transaction to acquire an additional working interest within the Corrib natural gas project and $23.0 million for a land acquisition.

​

Cash and cash equivalents was comprised of the following:

​

​ ​ ​ ​ ​
​ ​ As at
​ Dec 31, 2022 Dec 31, 2021
Cash on deposit with financial institutions 13,701 5,901
Guaranteed investment certificates 135 127
Cash and cash equivalents 13,836 6,028

​

Wages and benefits included in operating expenses and general and administration expenses were:

​

​ ​ ​ ​ ​
​ ​ Year Ended
​ Dec 31, 2022 Dec 31, 2021
Operating expense 75,165 73,739
General and administration expense 45,525 54,771
Wages and benefits 120,690 128,510

​

As at December 31, 2022, we had the following contractual obligations and commitments:

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​
(M) Less than 1 year **** 1 - 3 years **** 3 - 5 years **** After 5 years **** Total
Long-term debt (1) 69,235 533,362 225,861 634,875 1,463,333
Lease obligations 46,245 49,730 29,062 8,597 133,634
Processing and transportation agreements 40,267 52,786 23,133 101,629 217,815
Purchase obligations 27,481 4,907 444 285 33,117
Drilling and service agreements 5,051 58,122 — — 63,173
Total contractual obligations and commitments 188,279 698,907 278,500 745,386 1,911,072

All values are in US Dollars.

(1) Interest on revolving credit facility calculated assuming an annual interest rate of 6.19%.
(2) Commitments denominated in foreign currencies have been translated using the related spot rates on December 31, 2022.
--- ---

Vermilion Energy Inc.  ∎ Page 33 ∎  2022 Financial Statements

The following tables summarize Vermilion’s outstanding risk management positions as at December 31, 2022:

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ **** ​ **** ​ ​ **** Weighted **** ​ **** Weighted **** ​ **** Weighted **** ​ **** Weighted **** Daily **** Weighted
​ ​ ​ ​ ​ Daily ​ Average ​ Daily ​ Average ​ Daily ​ Average ​ Daily ​ Average ​ Bought ​ Average
​ ​ ​ ​ ​ Bought Put ​ Bought Put ​ Sold Call ​ Sold Call ​ Sold Put ​ Sold Put ​ Sold Swap ​ Sold Swap ​ Swap ​ Bought
​ Unit Currency Volume Price Volume Price Volume Price Volume Price Volume Swap Price
AECO
Q1 2023 ​ mcf ​ CAD 4,739 ​ 3.69 ​ 4,739 ​ 7.70 ​ — ​ — ​ 28,435 ​ 4.95 ​ — ​ —
Q2 2023 ​ mcf ​ CAD — ​ — ​ — ​ — ​ — ​ — ​ 14,217 ​ 4.19 ​ — ​ —
Q3 2023 ​ mcf ​ CAD — ​ — ​ — ​ — ​ — ​ — ​ 14,217 ​ 4.19 ​ — ​ —
Q4 2023 ​ mcf ​ CAD — ​ — ​ — ​ — ​ — ​ — ​ 4,791 ​ 4.19 ​ — ​ —
AECO Basis (AECO less NYMEX Henry Hub)
Q2 2023 ​ mcf ​ — ​ — ​ — ​ — ​ — ​ — ​ 23,000 ​ (1.13) ​ — ​ —
Q3 2023 ​ mcf ​ — ​ — ​ — ​ — ​ — ​ — ​ 23,000 ​ (1.13) ​ — ​ —
Q4 2023 ​ mcf ​ — ​ — ​ — ​ — ​ — ​ — ​ 7,750 ​ (1.13) ​ — ​ —
NYMEX Henry Hub
Q1 2023 ​ mcf ​ 24,000 ​ 4.00 ​ 24,000 ​ 8.44 ​ — ​ — ​ — ​ — ​ — ​ —
Q2 2023 mcf 5,000 4.00 5,000 8.75 — — — — — —
Q3 2023 mcf 5,000 4.00 5,000 8.75 — — — — — —
Q4 2023 mcf 1,685 4.00 1,685 8.75 — — — — — —

All values are in US Dollars.

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
​ **** ​ **** ​ ​ **** Weighted **** ​ **** Weighted **** ​ **** Weighted **** ​ **** Weighted **** Daily **** Weighted
​ ​ ​ ​ ​ Daily ​ Average ​ Daily ​ Average ​ Daily ​ Average ​ Daily ​ Average ​ Bought ​ Average
​ ​ ​ ​ ​ Bought Put ​ Bought Put ​ Sold Call ​ Sold Call ​ Sold Put ​ Sold Put ​ Sold Swap ​ Sold Swap ​ Swap ​ Bought
​ ​ Unit ​ Currency Volume ​ Price ​ Volume ​ Price ​ Volume ​ Price ​ Volume ​ Price ​ Volume ​ Swap Price
NBP
Q1 2023 mcf 18,426 11.76 18,426 19.54 14,740 4.10 — — — —
Q2 2023 mcf 7,370 11.48 7,370 17.46 4,913 4.40 — — — —
Q3 2023 mcf 2,457 22.71 2,457 35.90 — — — — — —
Q1 2024 mcf 4,913 41.03 4,913 84.26 — — — — — —
TTF ​ ​
Q1 2023 mcf 14,740 24.01 14,740 46.12 2,457 3.52 — — — —
Q2 2023 mcf 19,654 34.53 19,654 53.21 — — — — — —
Q3 2023 mcf 19,654 34.53 19,654 53.21 — — — — — —
Q4 2023 mcf 12,284 44.84 12,284 84.99 — — 3,685 67.41 — —
Q1 2024 ​ mcf ​ 31,938 ​ 40.69 ​ 31,938 ​ 78.00 ​ — ​ — ​ 3,685 ​ 67.41 ​ — ​ —
Q2 2024 ​ mcf ​ 3,593 ​ 37.56 ​ 3,593 ​ 74.66 ​ — ​ — ​ — ​ — ​ — ​ —
Q3 2024 ​ mcf ​ 3,593 ​ 37.56 ​ 3,593 ​ 74.66 ​ — ​ — ​ — ​ — ​ — ​ —

All values are in Euros.

​

​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
VET Equity Swaps **** Initial Share Price ​ Share Volume ​
Swap Jan 2020 - Apr 2023 ​ 20.9788 CAD ​ 2,250,000 ​
Swap Jan 2020 - Jul 2024 ​ 22.4587 CAD ​ 1,500,000 ​
​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​
Cross Currency Interest Rate ​ ​ **** Receive Notional Amount Receive Rate **** Pay Notional Amount **** Pay Rate ​
Swap January 2023 111,600,000 SOFR + 1.35% ​ 150,000,000 CAD CDOR + 0.88% ​

All values are in US Dollars.

​

​

20. Subsequent events

​

In the first quarter of 2022, we signed an agreement to sell an asset package in southeast Saskatchewan. The assets are comprised of approximately 5,500 boe/d of non-core light oil production in the greater Arcola and Queensdale areas of southeast Saskatchewan. Total cash consideration is $225 million, before closing adjustments. The transaction has an effective date of September 1, 2022 and is expected to close in March 2023. The net proceeds will be used to pay down our revolving credit facility.

​

Vermilion Energy Inc.  ∎ Page 34 ∎  2022 Financial Statements

DIRECTORS<br><br>​<br><br>Robert Michaleski ^1,3,5^<br><br>Calgary, Alberta<br><br>​<br><br>Dion Hatcher<br><br>Calgary, Alberta<br><br>​<br><br>James J. Kleckner Jr. ^7,9^<br><br>Edwards, Colorado<br><br>​<br><br>Carin Knickel ^4,7,11^<br><br>Golden, Colorado<br><br>​<br><br>Stephen P. Larke ^3,5,10^<br><br>Calgary, Alberta<br><br>​<br><br>Timothy R. Marchant ^6,9,11^<br><br>Calgary, Alberta<br><br>​<br><br>William Roby ^7,8,11^<br><br>Katy, Texas<br><br>​<br><br>Manjit Sharma ^2,5^<br><br>Toronto, Ontario<br><br>​<br><br>Myron Stadnyk ^7,9^<br><br>Calgary, Alberta<br><br>​<br><br>Judy Steele ^3,5,11^<br><br>Halifax, Nova Scotia<br><br>​<br><br>1<br><br>Chairman (Independent)<br><br>2<br><br>Audit Committee Chair (Independent)<br><br>3<br><br>Audit Committee Member (Independent)<br><br>4<br><br>Governance and Human Resources Committee Chair (Independent)<br><br>5<br><br>Governance and Human Resources Committee Member (Independent)<br><br>6<br><br>Health, Safety and Environment Committee Chair (Independent)<br><br>7<br><br>Health, Safety and Environment Committee Member (Independent)<br><br>8<br><br>Independent Reserves Committee Chair (Independent)<br><br>9<br><br>Independent Reserves Committee Member (Independent)<br><br>10<br><br>Sustainability Committee Chair (Independent)<br><br>11<br><br>Sustainability Committee Member (Independent) OFFICERS / CORPORATE SECRETARY<br><br>​<br><br>Dion Hatcher *<br><br>President & Chief Executive Officer<br><br>​<br><br>Lars Glemser *<br><br>Vice President & Chief Financial Officer<br><br>​<br><br>Terry Hergott<br><br>Vice President Marketing<br><br>​<br><br>Yvonne Jeffery<br><br>Vice President Sustainability<br><br>​<br><br>Darcy Kerwin *<br><br>Vice President International & HSE<br><br>​<br><br>Bryce Kremnica *<br><br>Vice President North America<br><br>​<br><br>Geoff MacDonald<br><br>Vice President Geosciences<br><br>​<br><br>Kyle Preston<br><br>Vice President Investor Relations<br><br>​<br><br>Averyl Schraven<br><br>Vice President People and Culture<br><br>​<br><br>Jenson Tan *<br><br>Vice President Business Development<br><br>​<br><br>Gerard Schut *<br><br>Vice President European Operations<br><br>​<br><br>Robert (Bob) J. Engbloom<br><br>Corporate Secretary<br><br>​<br><br>* Executive Committee<br><br>​<br><br>​ AUDITORS<br><br>​<br><br>Deloitte LLP<br><br>Calgary, Alberta<br><br>​<br><br>BANKERS<br><br>​<br><br>The Toronto-Dominion Bank<br><br>​<br><br>Alberta Treasury Branches<br><br>​<br><br>Bank of America N.A., Canada Branch<br><br>​<br><br>Canadian Imperial Bank of Commerce<br><br>​<br><br>Export Development Canada<br><br>​<br><br>National Bank of Canada<br><br>​<br><br>Royal Bank of Canada<br><br>​<br><br>The Bank of Nova Scotia<br><br>​<br><br>Wells Fargo Bank N.A., Canadian Branch<br><br>​<br><br>La Caisse Centrale Desjardins du Québec<br><br>​<br><br>Citibank N.A., Canadian Branch - Citibank Canada<br><br>​<br><br>Canadian Western Bank<br><br>​<br><br>JPMorgan Chase Bank, N.A., Toronto Branch<br><br>​<br><br>Goldman Sachs Lending Partners LLC<br><br>​<br><br>EVALUATION ENGINEERS<br><br>​<br><br>GLJ Petroleum Consultants Ltd.<br><br>Calgary, Alberta<br><br>​<br><br>LEGAL COUNSEL<br><br>​<br><br>Norton Rose Fulbright Canada LLP<br><br>Calgary, Alberta<br><br>​<br><br>TRANSFER AGENT<br><br>​<br><br>Odyssey Trust Company<br><br>​<br><br>STOCK EXCHANGE LISTINGS<br><br>​<br><br>The Toronto Stock Exchange (“VET”)<br><br>The New York Stock Exchange (“VET”)<br><br>​<br><br>INVESTOR RELATIONS<br><br>Kyle Preston<br><br>Vice President Investor Relations<br><br>403-476-8431 TEL<br><br>403-476-8100 FAX<br><br>1-866-895-8101 IR TOLL FREE<br><br>investor_relations@vermilionenergy.com

​

​

​

Vermilion Energy Inc.  ∎ Page 35 ∎  2022 Financial Statements

Exhibit 99.4

​

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

​

We consent to the incorporation by reference in Registration Statement No. 333-232837 on Form S-8 and to the use of our reports dated March 8, 2023 relating to the financial statements of Vermilion Energy Inc. and the effectiveness of Vermilion Energy Inc.'s internal control over financial reporting, appearing in this Annual Report on Form 40-F of Vermilion Energy Inc. for the year ended December 31, 2022.

​

/s/ Deloitte LLP

​

Chartered Professional Accountants Calgary, Canada

March 8, 2023

Exhibit 99.5

​

Graphic

CONSENT OF GLJ LTD.

​

We hereby consent to the use of and reference to our name and our reports, and the inclusion of information derived from our reports, evaluating Vermilion Energy Inc.’s (the “Company”) petroleum and natural gas reserves as at December 31, 2022, in the Company’s Annual Information Form, news releases and investor presentations.

​

Yours truly,
GLJ LTD.
Jodi L. Anhorn, M.Sc., P. Eng.
President & CEO

​

Calgary, Alberta

February 14, 2023

​

1920, 401 – 9^th^ Ave SW Calgary, AB, Canada T2P 3C5 I teI 403-266-9500 I gIjpc.com

EXHIBIT 99.6

​

VERMILION ENERGY INC.

CERTIFICATION OF THE CHIEF EXECUTIVE OFFICER

​

I, Dion Hatcher, President and Chief Executive Officer, certify that:

​

1.I have reviewed this annual report on Form 40-F of Vermilion Energy Inc.;

​

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 issuer as of, and for, the periods presented in this report;

​

4. The issuer’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 issuer 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 issuer, 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 issuer’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;

​

d) Disclosed in this report any change in the issuer’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 issuer’s internal control over financial reporting; and

​

5. The issuer’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the issuer’s auditors and the audit committee of the issuer’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 issuer’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 issuer’s internal control over financial reporting.

​

Date: March 8, 2023

​

/s/ Dion Hatcher
[Signature]
Dion Hatcher, President and Chief Executive Officer

​

​

EXHIBIT 99.6

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VERMILION ENERGY INC.

CERTIFICATION OF THE CHIEF FINANCIAL OFFICER

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I, Lars Glemser, Vice President and Chief Financial Officer, certify that:

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1. I have reviewed this annual report on Form 40-F of Vermilion Energy Inc.;

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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;

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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 issuer as of, and for, the periods presented in this report;

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4. The issuer’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 issuer and have:

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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 issuer, 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;

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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;

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c) Evaluated the effectiveness of the issuer’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;

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d) Disclosed in this report any change in the issuer’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 issuer’s internal control over financial reporting; and

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5. The issuer’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the issuer’s auditors and the audit committee of the issuer’s board of directors (or persons performing the equivalent functions):

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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 issuer’s ability to record, process, summarize and report financial information; and

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b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the issuer’s internal control over financial reporting.

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Date: March 8, 2023

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/s/ Lars Glemser
[Signature]
Lars Glemser, Vice President and Chief Financial Officer

​

EXHIBIT 99.7

​

VERMILION ENERGY INC.

CERTIFICATE OF THE CHIEF EXECUTIVE OFFICER

​

Pursuant to Section 906(a) of the Sarbanes-Oxley Act of 2002

Subsections (a) and (b) of Section 1350, Chapter 63 of Title 18 of the United States Code

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In connection with the annual report of Vermilion Energy Inc. (the “Corporation”) on Form 40-F for the fiscal year ended December 31, 2022, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Dion Hatcher, President and Chief Executive Officer of the Corporation, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

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1. The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

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2. The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Corporation.

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Dated at Calgary, Alberta, Canada this 8^th^ day of March 2023.

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​ ​
​ ("Dion Hatcher")
​ [Signature]
​ ​
​ Dion Hatcher, President and Chief Executive Officer

​

​

EXHIBIT 99.7

​

VERMILION ENERGY INC.

CERTIFICATE OF THE CHIEF FINANCIAL OFFICER

​

Pursuant to Section 906(a) of the Sarbanes-Oxley Act of 2002

Subsections (a) and (b) of Section 1350, Chapter 63 of Title 18 of the United States Code

​

In connection with the annual report of Vermilion Energy Inc. (the “Corporation”) on Form 40-F for the fiscal year ended December 31, 2022, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Lars Glemser, Vice President and Chief Financial Officer of the Corporation, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

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1. The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

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2. The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Corporation.

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Dated at Calgary, Alberta, Canada this 8th day of March 2023.

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​ ​
​ (“Lars Glemser”)
​ [Signature]
​ ​
​ Lars Glemser, Vice President and Chief Financial Officer

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