UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 20-F

(Mark One)

¨ REGISTRATION STATEMENT PURSUANT TO SECTION 12(b) OR 12(g) OF THE SECURITIES EXCHANGE ACT OF 1934

þ ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended December 31, 2023

¨ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

¨ SHELL COMPANY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

Date of event requiring this shell company report

For the transition period from to

Commission file number: 001-41870

Diversified Energy Company PLC
(Exact name of Registrant as specified in its charter)
Not Applicable	England and Wales
(Translation of Registrant’s name into English)	(Jurisdiction of incorporation or organization)
1600 Corporate Drive Birmingham,<br><br>Alabama 35242 Tel: +1 205 408 0909	Bradley G. Gray<br><br>Diversified Energy Company PLC<br><br>1600 Corporate Drive<br><br>Birmingham, Alabama 35242<br><br>Tel: +1 205 408 0909
(Address of principal executive offices)	(Name, Telephone, E-mail and/or Facsimile<br><br>number and Address of Company Contact<br><br>Person)

Securities registered or to be registered, pursuant to Section 12(b) of the Act

Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Ordinary shares, nominal (par) value £0.20 per share	DEC	New York Stock Exchange
Ordinary shares, nominal (par) value £0.20 per share	DEC	London Stock Exchange

Securities registered or to be registered pursuant to Section 12(g) of the Act: None

Securities for which there is a reporting obligation pursuant to Section 15(d) of the Act: None

Indicate the number of outstanding shares of each of the issuer’s classes of capital stock or common stock as of the close of the period covered by the annual report: N/A

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes ¨ No þ

If this report is an annual or transition report, indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or 15(d) of the Securities Exchange Act

of 1934. Yes ¨ No þ

Note — Checking the box above will not relieve any registrant required to file reports pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934 from their obligations

under those Sections.

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12

months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes þ No ¨

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 ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or an emerging growth company. See definition of “large

accelerated filer,” “accelerated filer,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

¨ Large accelerated filer	¨ Accelerated filer	þ Non-accelerated filer	¨ Emerging growth company

If an emerging growth company that prepares its financial statements in accordance with U.S. GAAP, indicate by check mark if the registrant has elected not to use the extended

transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨

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. ¨

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 which basis of accounting the registrant has used to prepare the financial statements included in this filing:

¨ U.S. GAAP	þ International Financial Reporting Standards as issued by the International Accounting Standards Board	¨ Other

If “Other” has been checked in response to the previous question indicate by check mark which financial statement item the registrant has elected to follow. Item 17 ¨ Item 18 ¨

If this is an annual report, indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ¨ No þ

(APPLICABLE ONLY TO ISSUERS INVOLVED IN BANKRUPTCY PROCEEDINGS DURING THE PAST FIVE YEARS)

Indicate by check mark whether the registrant has filed all documents and reports required to be filed by Sections 12, 13 or 15(d) of the Securities Exchange Act of 1934

subsequent to the distribution of securities under a plan confirmed by a court. Yes ¨ No ¨

2023

Annual Report

& FORM 20-F

Our Core Values<br><br>We CARE for each other, our communities, our industry<br><br>and our country!
COMMITMENT<br><br>—Seek opportunities for continuous learning<br><br>and improvement.<br><br>—Serve and support our teams and communities with<br><br>passion and enthusiasm.<br><br>ACCOUNTABILITY<br><br>—Act with personal and business integrity.<br><br>RESPECT<br><br>—Value the dignity and worth of all individuals.<br><br>—Respect environmental stewardship as we make<br><br>business decisions.<br><br>EXCELLENCE<br><br>—Commit to excellence in our performance.<br><br>—Exhibit courage of convictions, challenge the status quo<br><br>and strive to create value.		Strategic Report
---	---
8	Chairman’sand Chief Executive’s Statement
10	A Differentiated Business Model
12	Geographic Operating Areas
14	Strategy
19	Key Performance Indicators
36	Sustainability Review
73	Financial Review
91	Risk Management Framework
96	Risk Factors
119	Viability and Going Concern
Corporate Governance
122	The Chairman’s Governance Statement
128	Board of Directors
133	Directors’ Report
139	The Nomination&Governance Committee’s Report
142	The Audit&Risk Committee’s Report
148	The Remuneration Committee’s Report
153	Remuneration at a Glance
169	The Sustainability&Safety Committee’s<br><br>Report
Group Financial Statements
172	Report of Independent Registered Public Accounting<br><br>Firm
175	Consolidated Statement of Comprehensive Income
176	Consolidated Statement of Financial Position
177	Consolidated Statement of Changes in Equity
178	Consolidated Statement of Cash Flows
179	Notes to the Group Financial Statements
Additional Information (Unaudited)
231	Payments to Governments Report 2023
233	Alternative Performance Measures
237	Officers and Professional Advisors
238	Shareholder Information
246	Glossary of Terms
253	Signatures
248	Exhibits

We have prepared our financial statements and the notes thereto in accordance with IFRS as issued by the International Accounting Standards Board.

To provide metrics that we believe enhance the comparability of our results to similar companies, throughout this Annual Report & Form 20-F, we refer

to Alternative Performance Measures (“APMs”). APMs are intended to be used in addition to, and not as an alternative for the financial information

contained within the Group Financial Statements, nor as a substitute for IFRS. Within the APMs section located in the Additional Information section

within this Annual Report & Form 20-F, we define, provide calculations and reconcile each APM to its nearest IFRS measure. These APMs include

“adjusted EBITDA,” “net debt,” “net debt-to-adjusted EBITDA,” “total revenue, inclusive of settled hedges,” “adjusted EBITDA margin,” “free cash flow,”

“adjusted operating cost per Mcfe,” “employees, administrative costs and professional services,” and “PV-10.”

Diversified Energy Company PLC (the “Parent” or “Company”) and its

wholly owned subsidiaries (the “Group,” “DEC,” or “Diversified”) is an

independent energy company engaged in the production,

transportation and marketing of primarily natural gas.

Our proven business model creates sustainable value in today's natural gas market by investing in

producing assets, reducing emissions and improving asset integrity while generating significant, hedge-

protected cash flows. We Acquire, Optimize, Produce and Transport natural gas, natural gas liquids and oil

from existing wells then Retire our wells at the end of their life to optimally steward the resource already

developed by others within our industry, reducing the environmental footprint, while sustaining important

jobs and tax revenues for many local communities. While most companies in our sector are built to explore

and develop new reserves, we fully exploit existing reserves through our focus on safely and efficiently

operating existing wells to maximize their productive lives and economic capabilities, which in turn

reduces the industry’s footprint on our planet.

Key Achievements

Accretive Growth<br><br>Investment in the Tanos II<br><br>Central Region acquisition<br><br>totaled $262 million and<br><br>bolstered average daily<br><br>production by 8%.	Asset Monetization<br><br>Unlocked value on non-core<br><br>assets through the sale of<br><br>undeveloped acreage and<br><br>non-operated well interests<br><br>for total consideration of<br><br>$66 million.	U.S. Listing<br><br>Commenced trading on the<br><br>New York Stock Exchange<br><br>under the “DEC” ticker in<br><br>December 2023, expanding<br><br>access to U.S. investors and<br><br>improving trading liquidity.
Prioritizing Sustainability<br><br>Realized 33% year-over-year<br><br>reduction in Scope 1<br><br>methane intensity, achieving<br><br>our 2030 goal of cumulative<br><br>50% reduction in Scope 1<br><br>methane intensity (from<br><br>2020 baseline) and driven<br><br>largely by our focused and<br><br>continual emissions<br><br>detection, measurement and<br><br>mitigation programs in both<br><br>our Appalachia and Central<br><br>regions.	Financing<br><br>Executed the sale of certain<br><br>producing assets in<br><br>Appalachia to a special<br><br>purpose vehicle “SPV”,<br><br>generating proceeds of<br><br>approximately $192 million<br><br>through placement of an<br><br>asset-backed securitization at<br><br>the SPV, including the sale of<br><br>an 80% equity interest in the<br><br>SPV for $30 million.	Delivering Shareholder Value<br><br>Share buybacks and<br><br>distributed dividends<br><br>represent $179 million in<br><br>return of capital to<br><br>shareholders.
2	Diversified Energy Company PLC Annual Report and Form 20-F2023
---	---

Cross Reference to Form 20-F

			Pages
Part I
Item 1.	Identity of Directors, Senior Management and Advisers		N/A
Item 2.	Offer Statistics and Expected Timetable		N/A
Item 3.	Key Information
	A.	[Reserved]
	B.	Capitalization and indebtedness	N/A
	C.	Reasons for the offer and use of proceeds	N/A
	D.	Risk factors	96-118
Item 4.	Information on the Group
	A.	History and development of the Group	1, 4, 12-13, 22, 179, 245
	B.	Business overview	23-35
	C.	Organizational structure	181, Exhibit 8.1
	D.	Property, plants and equipment	4, 12, 184, 201, 215, 237
Item 4A.	Unresolved Staff Comments		N/A
Item 5.	Operating and Financial Review and Prospects
	A.	Operating results	74-84
	B.	Liquidity and capital resources	84
	C.	Research and development, patents and licenses, etc.	N/A
	D.	Trend information	90
	E.	Critical accounting estimates	90
Item 6.	Directors, Senior Management and Employees
	A.	Directors and senior management	124, 128-132
	B.	Compensation	211, 213
	C.	Board practices	124, 125, 126, 134, 140-140,<br><br>143-143, 150-150, 171-171,
	D.	Employees	65
	E.	Share ownership	134, 211, 213
	F.	Disclosure of a registrant’s action to recover erroneously awarded<br><br>compensation	N/A
Item 7.	Major Shareholders and Related Party Transactions
	A.	Major shareholders	134, 136
	B.	Related party transactions	226
	C.	Interests of experts and counsel	N/A
Item 8.	Financial Information
	A.	Consolidated Statements and Other Financial Information	172-227
	B.	Significant Changes	N/A
Item 9.	The Offer and Listing
	A.	Offer and listing details	179
	B.	Plan of distribution	N/A
	C.	Markets	179
	D.	Selling shareholders	N/A
	E.	Dilution	N/A
	F.	Expenses of the issue	N/A
2	Diversified Energy Company PLC Annual Report and Form 20-F2023
---	---
			Pages
---	---	---	---
Item 10.	Additional Information
	A.	Share capital	N/A
	B.	Memorandum and articles of association	Exhibit 1.1 & 1.2
	C.	Material contracts	238-239
	D.	Exchange controls	240
	E.	Taxation	240-244
	F.	Dividends and paying agents	N/A
	G.	Statement by experts	N/A
	H.	Documents on display	245
	I.	Subsidiary information	N/A
	J.	Annual report to security holders	N/A
Item 11.	Quantitative and Qualitative Disclosures About Market Risk		90, 223-225
Item 12.	Description of Securities Other than Equity Securities
	A.	Debt securities	N/A
	B.	Warrants and rights	N/A
	C.	Other securities	N/A
	D.	American depositary shares	N/A
Part II
Item 13.	Defaults, Dividend Arrearages and Delinquencies		N/A
Item 14.	Material Modifications to the Rights of Security Holders and Use of Proceeds		N/A
Item 15.	Controls and Procedures		245
Item 16.	[Reserved]		N/A
Item 16A.	Audit Committee Financial Expert		143
Item 16B.	Code of Ethics		135
Item 16C.	Principal Accountant Fees and Services		146, 195
Item 16D.	Exemptions from the Listing Standards for Audit Committees		N/A
Item 16E.	Purchases of Equity Securities by the Issuer and Affiliated Purchasers		N/A
Item 16F.	Change in Registrant’s Certifying Accountant		N/A
Item 16G.	Corporate Governance		N/A
Item 16H.	Mine Safety Disclosure		N/A
Item 16I.	Disclosure Regarding Foreign Jurisdictions that Prevent Inspections		N/A
Item 16J.	Insider Trading Policies		N/A
Item 16K.	Cybersecurity		95
Part III
Item 17.	Financial Statements		N/A
Item 18.	Financial Statements		172-229
Item 19.	Exhibits		248		Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	3
---	---	---	---	---

DEC at a Glance

Our Assets

Our assets primarily consist of long-life, low-decline natural gas wells and gathering systems located within the Appalachian

Basin and Central Region of the U.S., providing opportunistic synergies in our operations. Our headquarters are located in

Birmingham, Alabama with operational and field offices located throughout the states in which we operate.

4	Diversified Energy Company PLC Annual Report and Form 20-F2023

KEY

l Upstream assets

l Midstream assets

l States in which we operate

APPALACHIA ASSETS

CENTRAL ASSETS

05_426107-1_pic_key facts.jpg

Key Facts

| PRODUCTION MIX 86% natural gas 12% NGLs 2% oil | PRODUCTION 256,378 natural gas (MMcf) 5,832 NGLs (MBbls) 1,377 oil (MBbls) | PV-10 VALUE OF RESERVES $2.1 billion(a) 3,849,946 MMcfe | MIDSTREAM SYSTEM ~17,700 miles | | --- | --- | --- | --- || SCOPE 1 METHANE EMISSIONS INTENSITY 0.8 MT CO2e/MMcfe | NO LEAK RATE ON SURVEYED WELLS ~98% Group-wide | AERIALLY SURVEYED MIDSTREAM MILES ~10,000 miles | REPORTABLE SPILL INTENSITY 0.08 oil & water per MBbl | | --- | --- | --- | --- || NET INCOME $760 million | TOTAL REVENUE $868 million | ADJUSTED EBITDA MARGIN(b) 52% | ADJUSTED EBITDA(b) $543 million | | --- | --- | --- | --- | | (a)Based on SEC pricing. (b)Please refer to the APMs section in Additional Information within this Annual Report & Form 20-F for information on how these metrics are calculated and reconciled to IFRS measures. | | | | | Strategic Report | Corporate Governance | Group Financial Statements | Additional Information | 5 | | --- | --- | --- | --- | --- |

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6	Diversified Energy Company PLC Annual Report and Form 20-F2023

Strategic

Report

8	Chairman’s and Chief Executive’s Statement
10	A Differentiated Business Model
12	Geographic Operating Areas
14	Strategy
19	Key Performance Indicators
36	Sustainability
73	Financial Review
91	Risk Management Framework
96	Risk Factors
119	Viability and Going Concern
Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	7
---	---	---	---	---

Chairman’s Statement

8	Diversified Energy Company PLC Annual Report and Form 20-F2023

On behalf of the Board of Directors, I am pleased to share our financial and operational results that reflect the hard work, dedication, and focus of the entire Diversified team. Their consistent execution of our strategy and management initiatives has driven another year of strong environmental, financial, and operational performance. Throughout 2023, we continued to focus on cash flow generation, capital discipline, and balance sheet management. This, together with our resilient business model, means we have been able to deliver strong results which have benefited all stakeholders. In addition, we are proud of the part we are playing in responsibly providing the energy needed for our communities and country, as well as meeting growing demand beyond the U.S. Since 2017, Diversified’s demonstrated track record has delivered more than $800 million in returns to the Group’s stockholders including approximately $700 million in cash dividends paid and declared, along with approximately $110 million in share repurchases. The Board’s dedication to shareholder returns remains an absolute priority. We continuously refine the capital allocation framework in order to balance debt reduction, sustainable fixed dividends, strategic share repurchases and accretive acquisitions. We are proposing a final fourth quarter 2023 dividend of $0.29 which allows us to focus our cash flows on what we believe are the highest and best uses of capital. We are confident that this new level will be sustainable, and will also allow for continued debt reduction, more flexibility for alternative capital returns, and for funding future growth. We believe that our share price has been significantly undervalued for some while and has been affected by the structural de- equitization of the UK share market. We have, therefore, also authorized a share buyback program, which we believe will be an effective use of our capital and will further increase total shareholder returns. Part of our business model and strategy revolves around the continued addition of growth opportunities. We identified a listing on the New York Stock Exchange, in addition to the London listing, as an opportunity that could help to add significant value and were pleased to deliver on that key milestone this year. We view the NYSE listing as a great opportunity to expand access to U.S. investors and improve trading liquidity. We continue to evaluate opportunities to grow and to increasingly make Diversified the “Right Company at the Right Time.”

Another important part of our focused strategy is to create value through sustainability and stewardship. Over the past year, we have made significant progress with our methane emissions program, reducing emissions by over 33% from 2022 and achieving our 2030 goal meaningfully ahead of schedule. We are proud that we received recognition from the United Nations’ Oil & Gas Methane Partnership 2.0 (OGMP), being awarded the Gold rating for the second year. Our initiatives related to methane emission reductions are of paramount importance, and it gives us great confidence to see this recognized by international bodies. Operationally, we conducted over 246,000 leak detection surveys using industry-leading and proven detection equipment, and attaining a zero emissions rate of approximately 98%, proving the positive impact of our actions to eliminate methane leaks. Next LVL Energy, our asset retirement business, has continued to grow and contribute significantly to safe and efficient well retirements, retiring a total of 404 wells. This achievement included retiring a total of 222 Diversified wells in 2023, significantly exceeding state agreements. Additionally, our partnership with states on their orphan well programs resulted in 148 retired wells. We are immensely proud of the material investments we have made to lower our methane intensity, and to safely retire wells, and we remain focused on delivering continuous improvement. The Board and its Committees continue to operate effectively and are active in both supporting and challenging strategic discussions. There is an exceptional depth of knowledge and diversity of thinking. We again conducted a Board Performance Review during 2023 and will continue to ensure that we comply with all governance guidelines. As we look ahead to 2024 and beyond, I would like to recognize the quality of the team we have at Diversified, across the entire Group. I am very grateful for their work and look forward to future successes as a company in the years to come. In particular, I would like to thank the Executive Team, led by Rusty Hutson, Jr., who navigated the team through a year that has seen its share of broader challenges, notably an unfavorable commodity price environment. I also wish to express gratitude to our shareholders, lenders, and other stakeholders for their trust in our commitment to deliver long-term sustainable value and their support whilst we provide essential energy security and continue to care for our communities.

David E. Johnson Chairman of the Board March 19, 2024

“

Together with our

resilient business

model, we have been

able to deliver strong

results which have

benefited all

stakeholders.

Chief Executive’s Statement

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	9
The fundamental need for natural gas is well-<br><br>cemented in our domestic and global energy<br><br>outlooks. Natural gas is the essential fuel to<br><br>tackling global challenges – from enhancing energy<br><br>security of the United States and allies around the<br><br>world to addressing the universally shared need for<br><br>reliable, affordable, and sustainable power, natural<br><br>gas demand remains strong.<br><br>It’s against this backdrop of rising global energy<br><br>demand, consolidation in the U.S. energy markets,<br><br>and enhanced expectations for sustainably<br><br>produced energy that the case for Diversified’s<br><br>stewardship business model sharpens. Thanks to<br><br>our approach – focused on acquiring, improving,<br><br>and retiring existing, long-life U.S. energy assets<br><br>and honed through two decades of field<br><br>experience – Diversified is the “Right Company at<br><br>the Right Time” to responsibly manage existing<br><br>domestic natural gas and oil production in a<br><br>manner that’s consistent with environmental<br><br>stewardship and a lower-carbon energy future.<br><br>We continue to aggressively pursue this mission<br><br>each and every day, and 2023 was no different.<br><br>From closing the Tanos II acquisition – which<br><br>increased our footprint in the Central Region and<br><br>aligned with our stewardship and sustainability<br><br>commitments – to ending the year with dual-listing<br><br>on the New York Stock Exchange, 2023 was a year<br><br>focused on execution against our core business<br><br>objectives.<br><br>Through our focused commitment to responsible<br><br>asset management, we continue to drive methane<br><br>intensities downward, while returning wells to<br><br>production and gaining operational efficiencies.<br><br>Compared to a 2020 baseline, upstream methane<br><br>intensity has fallen over 50%, achieving our 2030<br><br>goal meaningfully ahead of schedule, and we are<br><br>continuing to take aggressive steps to optimize<br><br>environmental performance across our operating<br><br>areas. By viewing asset retirement as a business<br><br>opportunity, Diversified’s Next LVL Energy<br><br>subsidiary is the largest well retirement company in<br><br>Appalachia. Our focus on asset retirement stands<br><br>out, with our dedicated teams responsibly retiring<br><br>404 wells in 2023 alone, as no other company is<br><br>addressing state orphaned and end-of-life wells<br><br>head-on like we are.<br><br>This focus on sustainability principles has been<br><br>validated on the domestic and global stage, with<br><br>sustained Gold standard designations from the<br><br>United Nation’s Oil and Gas Methane Partnership<br><br>2.0 (second year), attainment of the second-<br><br>highest MSCI ESG “AA” rating, and multiple<br><br>sustainability awards, to name a few. Last year’s<br><br>sustainability report detailing our proactive<br><br>approach took home the ESG Report of the Year<br><br>by the international ESG Awards 2023 for speaking<br><br>to “both head and heart,” while also receiving the<br><br>top category nomination from IR Magazine. I am<br><br>proud to see the hard work of our employees<br><br>recognized as industry leaders time and again.<br><br>We also continue to expand Diversified’s<br><br>community-giving culture in the communities<br><br>where we live and work, and we’re privileged to<br><br>strengthen our corporate commitments to<br><br>employees. We fully recognize none of this<br><br>progress would be possible without our 1,600+<br><br>diligent team who work every day to ensure<br><br>families across the United States have safe, clean,<br><br>and reliable energy resources.	In the year ahead, we are taking a renewed focus<br><br>on the values on which Diversified was founded:<br><br>investing in strategic, aligned acquisitions that<br><br>scale our model and deliver greater operational<br><br>efficiencies, taking proactive steps to ensure the<br><br>sustainability of assets, keeping costs low and de-<br><br>leveraging the balance sheet – all while returning<br><br>value to shareholders.<br><br>Diversified has set in motion its “Focus Five” in<br><br>order to demonstrate meaningful expansion of<br><br>free cash flow generation while growing the<br><br>company in a disciplined manner. That plan<br><br>consists of the following core objectives:<br><br>—Optimized cash flow generation<br><br>—Cost structure optimization<br><br>—Financial and operational flexibility<br><br>—Sustainability innovation<br><br>—Scale through accretive growth<br><br>I believe these principles will help differentiate the<br><br>Company among its peers in unlocking corporate<br><br>value throughout 2024 and into the future.<br><br>The Company has undertaken a reassessment of<br><br>its capital allocation strategy to weigh the<br><br>intrinsic value of the current share price level<br><br>against the historical practice of returning capital<br><br>through dividends. The Board and executive<br><br>management team have jointly evaluated a<br><br>number of potential scenarios to align the<br><br>dividend level with expected future capital<br><br>allocation needs, peer trends, current commodity<br><br>prices and current equity market dynamics.<br><br>The result of this assessment is the Board’s<br><br>realignment of capital allocation and is designed<br><br>to best position the Company to create long-term<br><br>shareholder value through the proper<br><br>combination of:<br><br>—Systematic debt reduction<br><br>—Fixed per-share dividend<br><br>—Strategic share repurchases<br><br>—Accretive strategic acquisitions<br><br>We are proud to be part of the solution to the<br><br>broader challenge of existing energy<br><br>infrastructure and to do our part in driving our<br><br>country’s energy, climate, and economic security<br><br>– and we couldn’t do it without our OneDEC team.<br><br><br><br>Robert R. (“Rusty”) Hutson, Jr.<br><br>Chief Executive Officer<br><br>March 19, 2024
---	---

Diversified is the Right

Company at the Right

Time to responsibly

manage existing

domestic natural gas

and oil production in a

manner that’s

consistent with

environmental

stewardship and a

lower-carbon energy

future.

“

A Differentiated Business Model

1		ACQUIRE
	We maintain a disciplined approach to evaluating<br><br>opportunities to ensure that we only pursue those<br><br>that possess a consistent asset profile. We target<br><br>existing long-life, stable assets with synergistic<br><br>opportunities that produce predictable and stable<br><br>cash flows, are value accretive, margin enhancing<br><br>and strategically complementary.
2		OPTIMIZE
	The primarily mature nature of the assets we<br><br>acquire provides us with a portfolio of low-cost<br><br>optimization opportunities. These optimization<br><br>activities, applied through our internally<br><br>developed SAM program, are strategically<br><br>important as they aid in offsetting natural<br><br>production declines, creating expense efficiency<br><br>and reducing our emissions.
3		PRODUCE
	Our culture makes the difference as our team of<br><br>industry veterans strive to efficiently produce as<br><br>many units as possible in a safe and<br><br>environmentally responsible manner, aligning both<br><br>environmental and financial best interests.
4		TRANSPORT
	We seek to acquire midstream systems into which<br><br>we are a large producer and more fully integrate<br><br>those assets into our upstream portfolio to provide<br><br>immediate and long-term synergies.
5		RETIRE
	We embrace our commitment to be a responsible<br><br>operator of existing assets. With safety and<br><br>environmental stewardship as top priorities, we<br><br>design our asset retirement program to<br><br>permanently retire wells that have reached the end<br><br>of their producing lives. During 2022, we made<br><br>investments that allowed us to meaningfully<br><br>expand our asset retirement capabilities through a<br><br>series of acquisitions that we believe have provided<br><br>us with the operational capacity to be a leader in<br><br>asset retirement.			DAILY OPERATING PRIORITIES
---
Safety
No compromises. Ensuring the care and well-being of<br><br>our employees, our families, our partners and<br><br>communities is our top priority.
Production
Every unit counts. Ensuring that every unit we<br><br>safely produce provides affordable and reliable<br><br>energy to our communities and generates value for<br><br>our shareholders.
Efficiency
Every dollar counts. Ensuring every dollar we spend<br><br>protects our employees and communities and grows<br><br>the investment of our shareholders.
Enjoyment
Have fun delivering great results. Ensuring our<br><br>company is an attractive place to work,<br><br>encouraging innovation and celebrating our<br><br>employees’ accomplishments.
STRATEGY
Acquire long-life stable assets
Operate our assets in a safe, efficient and<br><br>responsible manner
Generate reliable free cash flow
Retire assets safely and responsibly
10	Diversified Energy Company PLC Annual Report and Form 20-F2023
---	---
Priorities	Strategy	Sustainability	Risk
---	---	---	---
see page 7	see page 11	see page 33	see page 79
Our business model and the corporate culture we cultivate is unique among the natural<br><br>gas and oil industry in that we do not engage in capital-intensive drilling and<br><br>development. Rather, our stewardship model focuses on acquiring existing long-life,<br><br>low-decline producing wells and, at times, their associated midstream assets, and then<br><br>efficiently managing the assets to improve or restore production, reduce unit operating<br><br>costs, reduce emissions and generate consistent free cash flow before safely and<br><br>permanently retiring those assets at the end of their useful lives.					Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	11
---	---	---	---	---
Execute Commodity Hedges<br><br>to Secure Healthy Margins
---
Protect our ability to provide<br><br>durable shareholder returns
Generate Reliable<br><br>Free Cash Flow
Maintain adjusted EBITDA<br><br>margins, low capital intensity<br><br>and low LOE per unit
Provide Durable<br><br>Shareholder Returns
Create value for our<br><br>shareholders via debt<br><br>reduction, fixed dividends,<br><br>strategic share repurchases<br><br>and accretive acquisitions
Maintain A Healthy<br><br>Balance Sheet
Maintain low leverage, ample<br><br>liquidity and access to<br><br>additional capital for<br><br>opportunistic growth

Geographic

Operating

Areas

U.S. NATURAL GAS PLAYS

Our Operating Areas

CENTRAL REGION

Our Central Region includes parts of Texas, Louisiana and Oklahoma, and is home to a number of asset rich natural gas and oil

formations. We currently operate within Texas, Louisiana and Oklahoma in the following plays:

Haynesville, Bossier and Cotton Valley

While in a relatively similar geographic region of East Texas

and West Louisiana, the Bossier shale lies directly above the

Haynesville shale but beneath the Cotton Valley sandstones.

A key benefit to operations in this region is the ability to

access consistent natural gas pipeline transportation from

the wellhead to the Gulf Coast, an area of strong demand

and advantageous pricing. This access to strong pricing and

takeaway capacity has made it a desirable area for

developers and one of rapid growth, particularly in the

Haynesville, with Cotton Valley and Bossier viewed as more

mature. As the wells in this region continue to mature and

decline rates continue to shallow and become more

predictable, it will be a fertile ground for our

continued expansion.

Barnett

An original shale play in the U.S., the Barnett shale is located

in North Texas and is a geological formation rich in natural

gas. The Barnett is home to some of the first horizontal

drilling and hydraulic stimulation that occurred in the early

1990s, unlocking the U.S. shale revolution. For a time during

the early 2000s, the Barnett was the largest natural gas

producing shale play in the U.S. Though drilling in this area

has largely subsided, the maturity of the play with its now

vast portfolio of low decline rate wells makes this area

available for opportunities to complement our existing

mature portfolio through future acquisitions.

Mid Continent

The Mid Continent region stretches across Oklahoma, Kansas

and the Texas panhandle and is generally understood to

reference the Fayetteville, Woodford, Granite Wash,

Springer, Sycamore and Cana Woodford shale natural gas

plays along with numerous other conventional and

unconventional natural gas reservoirs in the Arkoma Basin,

Ardmore Basin and Anadarko Basin. This mature and

developed region has undergone a redevelopment

renaissance over the last several years through the use of

hydraulic stimulation and horizontal drilling. It is an asset rich

environment with an abundance of mature wells and

developed transportation infrastructure making it a valuable

complement to our current portfolio.

12	Diversified Energy Company PLC Annual Report and Form 20-F2023

U.S. DRY SHALE GAS PRODUCTION<br><br>billion cubic feet per day
Sources: Graph by the U.S. Energy Information Administration (“EIA”) based on state administrative<br><br>data collected by Enverus. Data are through December 2023. The EIA updated the factors it uses to<br><br>convert gross natural gas to dry natural gas based on the latest data. The update affected historical<br><br>production volumes from some formations. State abbreviations indicate primary state(s).
Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	13
---	---	---	---	---
Current play - oldest play
---
Current play - intermedia depth/age play
Current play - shallowest/youngest play
Prospective play
Basin

APPALACHIA

The Appalachian Basin spans

Pennsylvania, Virginia, West Virginia,

Kentucky, Tennessee and Ohio and

consists of two productive unconventional

shale formations, the Marcellus Shale and

the slightly deeper Utica Shale. Together

they accounted for 38% of all U.S. dry

natural gas production in 2023. Diversified

began operating here in 2001, more than

twenty years ago, firmly establishing the

Group as a consolidator of assets and

exceptional operator. Appalachia is home

to many mature, low-decline conventional

and unconventional wells matching our

target asset profile.

| Strategy Our rapid growth and ability to generate consistent shareholder return stems from our unique business model and successful execution of straight-forward, low-risk, disciplined and proven operating techniques. | | --- || ACQUIRE Acquire long-life stable assets We practice a disciplined approach to acquire long-life stable assets by targeting low-decline producing assets that are value accretive, high margin and strategically complementary, while also applying extensive environmental, social, land and legal due diligence. | OPERATE Operate our assets in a safe, efficient and responsible manner Our operational strategy and success is closely aligned with the culture we created through our four guiding operational priorities: Safety, Production, Efficiency and Enjoyment. These four daily priorities are brought to life as part of our SAM program which our team lives and breathes every day as they work to safely deliver clean, affordable and reliable energy. | | --- | --- | | GENERATE Generate reliable free cash flow Our unique business model, coupled with the successful execution of the Acquire and Operate pillars of our corporate strategy, naturally lends itself to generating free cash flow. We aspire to make cash flows predictable and reliable so we can consistently generate shareholder return, pay down debt, fund acquisitive growth, and accomplish our sustainability goals and ambitions. | RETIRE Retire assets safely and responsibly At the appropriate time, through our safe and systematic asset retirement program, we safely and permanently retire wells and responsibly restore the well sites as close as possible to their original and natural condition. Our asset retirement program reflects our solid commitment to a healthy environment, the surrounding community and its citizens and state regulatory authorities. | | 14 | Diversified Energy Company PLC Annual Report and Form 20-F2023 | | --- | --- | | | Acquire Long-Life Stable Assets | | | --- | --- | --- | | ONE DEC Foster a culture of operational excellence through the integration of People, Process and Systems | | 2023 ACHIEVEMENTS —Completed the Tanos II Central Region acquisition for $262 million, contributing approximately 69 MMcfepd to 2023 production. —Realized first full year of operations for Next LVL Energy. — Utilized environmental and climate screening of target assets to inform acquisition considerations. TARGETS FOR 2024 — We will persist in our disciplined approach to acquisitions, focusing on producing assets that align with our stringent investment criteria. —We will maintain liquidity discipline, ensuring we remain well-positioned in the market to seize opportunities as they arise. —Our growth strategy will continue to emphasize complementary and synergistic expansion in the Appalachian and Central regions. We will foster strong relationships with development-oriented producers in our operating areas. —We will actively screen and execute on new basin opportunities, staying agile and responsive to emerging prospects. | | ACQUIRE Target low-decline, producing assets that complement our returns-focused strategy | | | | INTEGRATE Onboard employees, integrate processes and systems to drive efficiencies and standardization | | | | OPTIMIZE Empower retained personnel to apply our SAM techniques on acquired assets | | | | CONSOLIDATE Enhance operating, marketing relationships with increasing scale | | | | PRINCIPAL RISKS —Corporate Strategy and Acquisition Risk —Financial Strength and Flexibility Risk —Climate Risk | | KEY PERFORMANCE INDICATORS —Maintain net debt-to-adjusted EBITDA at or below 2.5x —Emissions intensity —Adjusted operating cost per Mcfe |

Indicates sustainability achievements and targets.

Strategic Report	Corporate Governance	Group Financial Statements
	Operate our Assets in a Safe,<br><br>Efficient and Responsible Manner
---	---	---
GOAL<br><br>Improve safety, optimize production, increase expense<br><br>efficiency and improve emissions profile		2023 ACHIEVEMENTS<br><br>—Annual production of 299,632 MMcfe.<br><br>—Adjusted EBITDA margin of 52%.<br><br>— Achieved 2023 goal to conduct fugitive emission <br><br><br>surveys on 100% of Central Region upstream assets.<br><br>— Collectively, conducted ~246,000 voluntary <br><br><br>fugitive emission detection surveys within our<br><br>upstream portfolio, confirming an average ~98% no-<br><br>leak rate on surveyed sites and allowing us to take<br><br>meaningful steps towards reducing our<br><br>emissions profile.<br><br>— Completed aerial light detection and ranging <br><br><br>(“LiDAR”) surveys covering~10,000 miles of<br><br>midstream systems which also included ~9,000 sites<br><br>(wells, compressor stations and other facilities).<br><br>— Zero non-compliance issues cited after <br><br><br>participating in 16 state and federal regulatory agency<br><br>audits of our operational assets and compliance<br><br>programs which were completed as part of routine<br><br>monitoring programs.<br><br>— Our safety-no compromises culture contributed to <br><br><br>our preventable motor vehicle accident rate (“MVA”)<br><br>declining 20% year-over-year to 0.55 (accidents to<br><br>million miles driven).<br><br>— Expanding continuous remote monitoring <br><br><br>capabilities through our Gas Control and Integrated<br><br>Operations Centers promotes safety and efficiency<br><br>through enhanced visibility of operations.<br><br>TARGETS FOR 2024<br><br>—We will continue to execute our guiding priorities:<br><br>Safety, Production, Efficiency, and Enjoyment.<br><br>— Our commitment to responsible stewardship <br><br><br>remains unwavering. We will intensely focus on<br><br>continuous improvement across all<br><br>sustainability aspects, aiming to exceed our<br><br>stakeholders’ expectations.<br><br>—We will maintain our focus on the SAM program to<br><br>uphold margins, offset natural declines, and capitalize<br><br>on expense efficiency opportunities.
PROCESS<br><br>“Data + Human Interaction” coupled with production<br><br>technology systems, drive activities, process enhancements,<br><br>refine best practice techniques
RESULT<br><br>Practical, profit-focused SOLUTIONS developed by our<br><br>experienced teams
ONGOING INITIATIVES
PRINCIPAL RISKS<br><br>—Corporate Strategy and Acquisition Risk<br><br>—Climate Risk<br><br>—Cybersecurity Risk<br><br>—Health and Safety Risk<br><br>—Regulatory and Political Risk<br><br>—Financial Strength and Flexibility Risk		KEY PERFORMANCE INDICATORS<br><br>—Safety Performance<br><br>—Emissions intensity<br><br>—Consistent adjusted EBITDA margin<br><br>—Adjusted operating cost per Mcfe<br><br>—Net cash provided by operating activities

Indicates sustainability achievements and targets.

16	Diversified Energy Company PLC Annual Report and Form 20-F2023
	Generate Reliable<br><br>Free Cash Flow
---	---	---
PRUDENT ALLOCATION OF<br><br>CASH FLOW		2023 ACHIEVEMENTS<br><br>—Raised our weighted average hedge floor on natural<br><br>gas production to $3.87 per Mcf at December 31,<br><br>2023 from $3.63 per Mcf at December 31, 2022.<br><br>—Repaid $277 million in asset backed securitizations<br><br>illustrating the substantial cash flow generated by our<br><br>assets.<br><br>—Repurchased 646,762 shares through our Share<br><br>Buyback Program, representing $11 million in<br><br>shareholder value above and beyond the $168 million<br><br>in dividend distributions.<br><br>— Delivered on our sustainability investment <br><br><br>commitment to convert additional natural gas<br><br>pneumatic devices to compressed air, converting 58<br><br>well pads exceeding our goal to convert 30 well pads.<br><br>We also had significant success with our upstream<br><br>emissions detection surveys, completed year two of<br><br>aerial surveillance activities for our midstream assets,<br><br>and contributed to tree planting and land<br><br>preservation initiatives primarily with West Virginia<br><br>State University.<br><br>TARGETS FOR 2024<br><br>—We will maintain our effective hedging strategy to<br><br>insulate cash flows. Additionally, we’ll make the most<br><br>of accretive market opportunities to raise our hedge<br><br>book floor.<br><br>— Our focus remains on securing low-cost <br><br><br>sustainability-linked financing. This will support our<br><br>acquisitive growth while ensuring low leverage and<br><br>ample liquidity.<br><br>— We will continue to invest in sustainability <br><br><br>initiatives, reinforcing our commitment to responsible<br><br>practices.
Allocating Cash Flow
	Debt Repayment<br><br>Reduce outstanding debt & create liquidity
	Reinvestment & Growth<br><br>Reinvest for organic growth & reduce<br><br>reliance on equity and debt markets
	Sustainability<br><br>Invest in broad spectrum of<br><br>sustainability initiatives
	Dividend Distributions<br><br>Pay sustainable dividends
	Share Buyback Program<br><br>Reduce outstanding shares & increase<br><br>shareholder value
PRINCIPAL RISKS<br><br>—Corporate Strategy and Acquisition Risk<br><br>—Commodity Price Volatility Risk<br><br>—Financial Strength and Flexibility Risk		KEY PERFORMANCE INDICATORS<br><br>—Maintain net debt-to-adjusted EBITDA at or<br><br>below 2.5x<br><br>—Consistent adjusted EBITDA margin<br><br>—Emissions intensity<br><br>—Adjusted operating cost per Mcfe<br><br>—Net cash provided by operating activities

Indicates sustainability achievements and targets.

Strategic Report	Corporate Governance	Group Financial Statements
	Retire Assets Safely and<br><br>Responsibly and Restore the<br><br>Environment to its Natural State
---	---	---
	STEP 1<br><br>DEACTIVATION<br><br>Remove product from<br><br>production equipment.	2023 ACHIEVEMENTS<br><br>— We expanded our asset retirement operations from 15 to <br><br><br>17 rigs.<br><br>— We successfully retired 222 DEC wells, including 21 Central <br><br><br>Region wells. This achievement surpasses our goal of retiring<br><br>200 wells by 2023 and also exceeds our collective state<br><br>commitments in Appalachia to retire 80 wells in our primary<br><br>states of operation.<br><br>— We further retired 182 third-party wells, including 148 <br><br><br>state and federal orphan wells and 34 for other third party<br><br>operators, bringing the total wells retired in Appalachia by<br><br>the Next LVL team to 383 wells.<br><br>— We permanently retired 18 wells on lands managed by the <br><br><br>Pennsylvania Game Commission. We then restored well sites<br><br>to their natural condition by planting native trees to the<br><br>region. This dual effort not only reduced noise pollution but<br><br>also contributed to the restoration of bird habitats.<br><br>TARGETS FOR 2024<br><br>— Continue to safely retire wells and aim to exceed state <br><br><br>asset retirement programme commitments by identifying<br><br>and retiring wells at the end of their productive lives.<br><br>— Continue to optimize the vertical integration benefits <br><br><br>we can realize with our expanded internal asset<br><br>retirement capacity.<br><br>— Continue constructive and collaborative dialogue with <br><br><br>states and industry associations to innovate and ensure best<br><br>practices in the well retirement arena.
	STEP 2<br><br>WELL DECOMMISSIONING<br><br>Permanently plug and<br><br>cap wellbore.
	STEP 3<br><br>SITE DECOMMISSIONING<br><br>Remove and salvage/dispose<br><br>of equipment.
	STEP 4<br><br>RECLAMATION<br><br>Redistribute soil and revegetate for<br><br>return to original state.
PRINCIPAL RISKS<br><br>—Health and Safety Risk<br><br>—Regulatory and Political Risk<br><br>—Climate Risk<br><br>—Financial Strength and Flexibility Risk		KEY PERFORMANCE INDICATORS<br><br>—Net cash provided by operating activities<br><br>—Meet or exceed state asset retirement goals<br><br>—Emissions intensity

Indicates sustainability achievements and targets.

18	Diversified Energy Company PLC Annual Report and Form 20-F2023

Key Performance Indicators

In assessing our performance, the Directors use key performance indicators (“KPIs”) to track our success against our stated

strategy. The Directors assess our KPIs on an annual basis and modify them as needed, taking into account current business

developments. The following KPIs focus on corporate and environmental responsibility, consistent cash flow generation

underpinned by prudent cost management, low leverage and adequate liquidity to protect the sustainability of the business.

Please refer to the APMs section in Additional Information within this Annual Report & Form 20-F for information on how

these metrics are calculated and reconciled to IFRS measures.

MAINTAIN NET DEBT-TO-ADJUSTED EBITDA AT OR<br><br>BELOW 2.5x<br><br>During 2023 our leverage ratio remained consistent at 2.3x and within our<br><br>preferred goal of 2.0x to 2.5x.<br><br>LINK TO STRATEGY<br><br>—Acquire long-life stable assets<br><br>—Generate reliable free cash flow<br><br>(a)2023 is pro forma for the Tanos II acquisition completed in March 2023. 2022 is pro<br><br>forma for the East Texas Assets and ConocoPhillips acquisitions. 2021 is pro forma for<br><br>the Indigo, Blackbeard, Tanos and Tapstone acquisitions as well as Oaktree’s<br><br>subsequent participation in the Indigo transaction.	NET DEBT-TO-PRO FORMA<br><br>ADJUSTED EBITDA(a)<br><br>
CONSISTENT ADJUSTED EBITDA MARGIN<br><br>Total revenue, inclusive of settled hedges for 2023 was $1,046 million, an<br><br>increase of 2% compared to 2022. Adjusted EBITDA for 2023 was $543 million,<br><br>an increase of 8% compared to 2022.<br><br>LINK TO STRATEGY<br><br>—Generate reliable free cash flow<br><br>—Operate our assets in a safe, efficient and responsible manner	ADJUSTED EBITDA MARGIN<br><br>
---	---
Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	19
---	---	---	---	---
ADJUSTED OPERATING COST PER MCFE<br><br>Adjusted operating cost per Mcfe for 2023 was $1.76, a decrease of 1%<br><br>compared with 2022.<br><br>LINK TO STRATEGY<br><br>—Operate our assets in a safe, efficient and responsible manner<br><br>—Generate reliable free cash flow	ADJUSTED OPERATING COST<br><br>PER MCFE<br><br>
---	---
NET CASH PROVIDED BY OPERATING ACTIVITIES<br><br>Net cash provided by operating activities for 2023 was $410 million an increase<br><br>of 6% compared with 2022.<br><br>LINK TO STRATEGY<br><br>—Operate our assets in a safe, efficient and responsible manner<br><br>—Generate reliable free cash flow<br><br>—Retire assets safely and responsibly and restore the environment to its<br><br>natural state	NET CASH PROVIDED BY<br><br>OPERATING ACTIVITIES<br><br>
---	---
EMISSIONS INTENSITY<br><br>Significant improvement in our Scope 1 methane emissions intensity is primarily<br><br>a result of our team’s steadfast focus on leak detection and mitigation across<br><br>our portfolio, including meeting current year objectives to survey 100% of<br><br>Central Region upstream assets while continuing like surveys in Appalachia to<br><br>maintain no leak rates. Conversion of natural gas-driven pneumatic devices to<br><br>compressed air also supported this tremendous achievement of a 33% year-<br><br>over-year reduction.<br><br>LINK TO STRATEGY<br><br>—Acquire long-life stable assets<br><br>—Operate our assets in a safe, efficient and responsible manner<br><br>—Generate reliable free cash flow<br><br>—Retire assets safely and responsibly and restore the environment to its<br><br>natural state	METHANE EMISSIONS INTENSITY<br><br>(MT CO2e/MMcfe)<br><br>
---	---
20	Diversified Energy Company PLC Annual Report and Form 20-F2023
---	---
MEET OR EXCEED STATE ASSET RETIREMENT GOALS<br><br>During 2023, we meaningfully expanded our asset retirement operations and<br><br>permanently retired 222 wells, inclusive of our Central Regions operations. This<br><br>achievement allowed us to more than double our Appalachian state<br><br>requirements of 80 wells and exceed our goal to retire 200 wells by the end of<br><br>2023. Additionally, with our Next LVL Energy assets, we plugged 182 wells for<br><br>third parties, including other operators and for the states of Ohio, Pennsylvania<br><br>and West Virginia.<br><br>LINK TO STRATEGY<br><br>—Retire assets safely and responsibly and restore the environment to its<br><br>natural state<br><br>(a)DEC wells inclusive of 14 and 21 Central Region wells retired during 2022 and<br><br>2023, respectively.	ACTUAL WELLS RETIRED(a)<br><br>
---	---
SAFETY PERFORMANCE<br><br>Our 2023 MVA rate is 0.55 incidents per million miles driven, a 20%<br><br>improvement from 2022. Though five of nine operating areas incurred zero<br><br>incidents in 2023, including two states who have not recorded an incident in<br><br>more than four years, TRIR increased to 1.28, primarily driven by an increase in<br><br>reported incidents in the remaining areas, in part a function of short-service<br><br>employees with less than one year experience under the Group’s safety<br><br>expectations. A new Safety Strategy Committee has been created to identify<br><br>and advance specific areas for improvement and accountability.<br><br>LINK TO STRATEGY<br><br>—Operate our assets in a safe, efficient and responsible manner	MOTOR VEHICLE ACCIDENTS &<br><br>TOTAL RECORDABLE<br><br>INCIDENT RATE<br><br>
---	---
Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	21
---	---	---	---	---

Our Business

HISTORY AND DEVELOPMENT OF THE GROUP

The Group, formerly Diversified Gas & Oil PLC, is an

independent energy company engaged in the production,

transportation and marketing of natural gas as well as oil

from its complementary onshore upstream and midstream

assets, primarily located within the Appalachian and Central

Regions of the United States. Our Appalachia assets consist

primarily of producing wells in conventional reservoirs and

the Marcellus and Utica shales, within Pennsylvania, Ohio,

Virginia, West Virginia, Kentucky, and Tennessee, while our

Central Region, located in Oklahoma, Louisiana, and

portions of Texas, includes producing wells in multiple

producing formations, including the Bossier, Haynesville

Shale and Barnett Shale Plays, as well as the Cotton Valley

and the Mid-Continent producing areas. The Group was

incorporated in 2014 in the United Kingdom, and our

predecessor business was founded in 2001 by our Chief

Executive Officer, Robert Russell (“Rusty”) Hutson, Jr., with

an initial focus on primarily natural gas and also oil

production in West Virginia. In recent years, we have grown

rapidly by capitalizing on opportunities to acquire and

enhance producing assets and leveraging the operating

efficiencies that result from economies of scale. Since 2017,

and through December 31, 2023, we have completed 24

acquisitions for a combined purchase price of

approximately $2.7 billion. We had average daily net

production of 821 MMcfepd and 811 MMcfepd for the years

ended December 31, 2023 and December 31,

2022, respectively.

We have consistently driven our operations towards

sustainability and efficiency throughout our history, but we

believe we are also at the forefront of U.S. natural gas and

oil producers in our commitment to sustainability goals.

While the global energy economy is reliant on natural gas

as an energy source, we believe it is imperative that natural

gas wells and pipelines be operated by responsible owners

with a strong commitment to the environment, and we

believe our operational track record demonstrates that

responsibility and stewardship. Given our operational focus

on efficient, environmentally sound natural gas production,

we believe we are ideally positioned to help serve current

energy demands and play a key role in the clean

energy transition.

Other Information

We were incorporated as a public limited company with the

legal name Diversified Gas & Oil PLC under the laws of the

United Kingdom on July 31, 2014 with the company number

On May 6, 2021, we changed our company name

to Diversified Energy Company PLC.

Our registered office is located at 4th Floor Phoenix House,

1 Station Hill, Reading, Berkshire United Kingdom, RG1 1NB.

In February 2017, our shares were admitted to trading on

the AIM Market of the London Stock Exchange (“AIM”)

under the ticker “DGOC.” In May 2020, our shares were

admitted to the premium listing of the Official List of the

Financial Conduct Authority and to trading on the Main

Market of the LSE. With the change in corporate name in

2021, our shares listed on the LSE began trading under the

new ticker “DEC.” In December 2023, the Group’s shares

were admitted to trading on the New York Stock Exchange

(“NYSE”) under the ticker “DEC.” As of December 31, 2023,

the principal trading market for the Group’s ordinary shares

was the LSE.

Our principal executive offices are located at 1600

Corporate Drive, Birmingham, Alabama 35242, and our

telephone number at that location is +1 205 408 0909. Our

website address is www.div.energy. The information

contained on, or that can be accessed from, our website

does not form part of this Annual Report & Form 20-F. We

have included our website address solely as an inactive

textual reference.

22	Diversified Energy Company PLC Annual Report and Form 20-F2023

Safety<br><br>No compromises<br><br>Ensuring the care and wellbeing of our employees, our families and our communities<br><br>is our top priority
Production<br><br>Every unit counts<br><br>Ensuring every unit we safely produce provides affordable, reliable energy to our<br><br>communities and generates value for our shareholders
Efficiency<br><br>Every dollar counts<br><br>Ensuring every dollar we spend protects our employees, our communities and the<br><br>investment of our shareholders
Enjoyment<br><br>Have fun delivering great results<br><br>Ensuring our company is a great place to work, encouraging innovation and<br><br>celebrating our employees’ accomplishments

BUSINESS OVERVIEW

Our strategy is primarily to acquire and manage natural gas

and oil properties while leveraging our associated

midstream assets to maximize cash flows. We seek to

improve the performance and operations of our acquired

assets through our deployment of rigorous field

management programs and/or refreshing infrastructure.

Through operational efficiencies, we demonstrate our

ability to maximize value by enhancing production while

lowering costs and improving well productivity. We adhere

to stringent operating standards, with a strong focus on

health, safety and the environment to ensure the safety of

our employees and the local communities in which we

operate. We believe that acting as a careful steward of our

assets will improve revenue and margins through captured

natural gas emissions while reducing operating costs, which

benefits our profitability. This focus on operational

excellence, including the aim of reducing natural gas

emissions, also benefits the environment and communities

in which we operate.

OUR BUSINESS STRATEGY

—Optimization of long-life, low-decline assets to enhance

margins and improve cash flow

—Generate consistent shareholder returns through vertical

integration, strategic hedging and cost optimization

—Disciplined growth through accretive acquisitions of

producing assets

—Maintain a strong balance sheet with ability to

opportunistically access capital markets

—Operate assets in a safe, efficient manner with what we

believe are industry-leading sustainability initiatives

OUR STRENGTHS

—Low-risk and low-cost portfolio of assets

—Long-life and low-decline production

—High margin assets benefiting from significant scale and

owned midstream and asset retirement infrastructure

and internal product marketing team

—Highly experienced management and operational team

—Track record of successful consolidation and integration

of acquired assets

OUTLOOK

Looking forward, we will continue to prudently manage our

long-life, low-decline asset portfolio and the consistent

cashflows they produce. We plan to maintain our hedging

strategy to protect cash flow. We will seek to retain our

strategic advantages in purposeful growth through a

disciplined acquisition strategy that continues to secure

low-cost financing that supports acquisitive growth while

maintaining low leverage and ample liquidity. In addition,

we intend to remain proactive in our sustainability

endeavors by seeking to secure future capital allocation for

sustainability initiatives.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	23

RESERVE DATA

Summary of Reserves

The following table presents our estimated net proved reserves, Standardized Measure and PV-10 as of December 31, 2023,

using SEC pricing. Standardized Measure has been presented inclusive and exclusive of taxes and is based on the proved

reserve report as of such date by Netherland, Sewell & Associates, Inc. (“NSAI”), our independent petroleum engineering firm.

A copy of the proved reserve report is included as an exhibit to the Annual Report & Form 20-F. Refer to the Preparation of

Reserve Estimates and Estimation of Proved Reserves sections within this Annual Report & Form 20-F for a definition of

proved reserves and the technologies and economic data used in their estimation.

	December 31, 2023
	SEC Pricing(a)
Proved developed reserves
Natural gas (MMcf)	3,184,499
NGLs (MBbls)	94,391
Oil (MBbls)	12,380
Total proved developed reserves (MMcfe)	3,825,125
Proved undeveloped reserves
Natural gas (MMcf)	15,545
NGLs (MBbls)	1,310
Oil (MBbls)	236
Total proved undeveloped reserves (MMcfe)	24,821
Total proved reserves
Natural gas (MMcf)	3,200,044
NGLs (MBbls)	95,701
Oil (MBbls)	12,616
Total proved reserves (MMcfe)	3,849,946
Prices used
Natural gas (Mmbtu)	$2.64
Oil and NGLs (Bbls)	$78.21
PV-10 (thousands)
Pre-tax (Non-GAAP)(b)	$2,139,690
PV of Taxes	(394,154)
Standardized Measure	$1,745,536
Percent of estimated total proved reserves that are:
Natural gas	83%
Proved developed	99%
Proved undeveloped	1%

(a)Our estimated net proved reserves were determined using average first-day-of-the-month prices for the prior 12 months in accordance with

SEC guidance. For natural gas volumes, the average Henry Hub spot price of $2.64 per MMBtu as of December 31, 2023 was adjusted for

gravity, quality, local conditions, gathering and transportation fees, and distance from market. For NGLs and oil volumes, the average WTI

price of $78.21 per Bbl as of December 31, 2023 was similarly adjusted for gravity, quality, local conditions, gathering and transportation fees,

and distance from market. All prices are held constant throughout the lives of the properties.

(b)The PV-10 of our proved reserves as of December 31, 2023 was prepared without giving effect to taxes or hedges. PV-10 is a non-GAAP and

non-IFRS financial measure and generally differs from Standardized Measure, the most directly comparable GAAP measure, because it does

not include the effects of income taxes on future net cash flows. We believe that the presentation of PV-10 is relevant and useful to our

investors as supplemental disclosure to the Standardized Measure because it presents the discounted future net cash flows attributable to

our reserves prior to taking into account future corporate income taxes and our current tax structure. While the Standardized Measure is free

cash dependent on the unique tax situation of each company, PV-10 is based on a pricing methodology and discount factors that are

consistent for all companies. Because of this, PV-10 can be used within the industry and by creditors and securities analysts to evaluate

estimated net cash flows from proved reserves on a more comparable basis. Investors should be cautioned that neither PV-10 nor the

Standardized Measure represents an estimate of the fair market value of our proved reserves.

Proved Reserves

As of December 31, 2023, our estimated proved reserves totaled 3,849,946 MMcfe, a decrease of 24% from the prior year-end

with a Standardized Measure of $1.7 billion. Natural gas constituted approximately 83% of our total estimated proved reserves

and 83% of our total estimated proved developed reserves. The following table provides a summary of the changes in our

proved reserves during the years ended December 31, 2023, 2022 and 2021.

24	Diversified Energy Company PLC Annual Report and Form 20-F2023
	Total (MMcfe)
---	---
Total proved reserves as of December 31, 2020	3,250,588
Extensions and discoveries	—
Revisions to previous estimates	541,509
Purchase of reserves in place	1,260,514
Sales of reserves in place	(164,039)
Production	(259,543)
Total proved reserves as of December 31, 2021	4,629,029
Extensions and discoveries	13,326
Revisions to previous estimates	379,812
Purchase of reserves in place	331,043
Sales of reserves in place	(6,912)
Production	(296,121)
Total proved reserves as of December 31, 2022	5,050,177
Extensions and discoveries	1,012
Revisions to previous estimates	(659,379)
Purchase of reserves in place	126,803
Sales of reserves in place	(369,035)
Production	(299,632)
Total proved reserves as of December 31, 2023	3,849,946

Extensions and Discoveries

During 2023, 1,012 MMcfe were adjusted due to well assignments recorded in the accounting actuals.

During 2022, we elected to participate in select development activities on a non-operated basis generating 13,326 MMcfe

in reserves.

During 2021, no reserves were added from extension or discovery activities.

Revisions to Previous Estimates

During 2023, we recorded 659,379 MMcfe in revisions to previous estimates. The downward revisions were primarily

associated with changes in the trailing 12-month average realized Henry Hub first day spot price, which decreased

approximately 58% as compared to the December 31, 2022 along with a 17% decrease in the 12 month average WTI first day

spot price. These factors primarily drove a net downward revision that impacted well economics and well life.

During 2022, we recorded 379,812 MMcfe in revisions to previous estimates. These positive performance revisions were

primarily associated with changes in the trailing 12-month average realized Henry Hub spot price, which increased

approximately 77% as compared to the December 31, 2021 Henry Hub spot price due to the war between Russia and Ukraine,

as well as other geopolitical factors. These factors primarily drove a net upward revision of 386,064 MMcfe due to changes in

pricing that impacted well economics. These increases were offset by a 6,252 MMcfe downward revision for changes in timing.

During 2021, 541,509 MMcfe in revisions to previous estimates were primarily associated with changes in the 12-month average

realized Henry Hub spot price, which increased approximately 81% as compared to December 31, 2020.

Purchase of Reserves in Place

During 2023, 126,803 MMcfe of purchases of reserves in place were associated with the Tanos II acquisition. Refer to Note 5 in

the Notes to the Group Financial Statements for additional information about these acquisitions.

During 2022, 331,043 MMcfe of purchases of reserves in place were associated with the East Texas and ConocoPhillips

acquisitions. Refer to Note 5 in the Notes to the Group Financial Statements for additional information about

these acquisitions.

During 2021, 1,260,514 MMcfe of purchases of reserves in place were associated with the Indigo, Tanos, Blackbeard and

Tapstone acquisitions. Refer to Note 5 in the Notes to the Group Financial Statements for additional information about these

acquisitions.

Sales of Reserves in Place

During 2023, 369,035 MMcfe of sales of reserves in place were primarily associated with the divestitures of non-core assets.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	25

During 2022, 6,912 MMcfe of sales of reserves in place were primarily associated with the divestitures of non-core assets.

During 2021, 164,039 MMcfe of sales of reserves in place were primarily associated with the divestment of assets to Oaktree for

their subsequent participation in the Indigo acquisition. Refer to Note 5 in the Notes to the Group Financial Statements for

additional information about divestitures.

Proved Undeveloped Reserves

We aim to obtain proved developed producing wells through acquisitions in accordance with our growth strategy rather than

through development activities. We accordingly contribute limited capital to development activities. From time to time, when

acquiring packages of wells, we will acquire certain locations that are in development by the acquiree at the time of the

acquisition or could be developed in the future. When economic, we will engage third parties to complete the existing

development activities, and such reserves are included below as proved undeveloped reserves. We do not have a

development program and, as a result, any additional undrilled locations that we hold cannot be classified as undeveloped

reserves in accordance with SEC rules unless a development plan is in place. As of December 31, 2023, we had no such

development plans and therefore have not classified these undrilled locations as proved undeveloped reserves.

The following table summarizes the changes in our estimated proved undeveloped reserves during the years ended

December 31, 2023, 2022 and 2021:

	Total (MMcfe)
Proved undeveloped reserves as of December 31, 2020	—
Extensions and discoveries	—
Revisions to previous estimates	—
Purchase of reserves in place	3,505
Sales of reserves in place	—
Converted to proved developed reserves	—
Proved undeveloped reserves as of December 31, 2021	3,505
Extensions and discoveries	8,832
Revisions to previous estimates	—
Purchase of reserves in place	—
Sales of reserves in place	—
Converted to proved developed reserves	(3,505)
Proved undeveloped reserves as of December 31, 2022	8,832
Extensions and discoveries	—
Revisions to previous estimates	—
Purchase of reserves in place	24,821
Sales of reserves in place	(8,832)
Converted to proved developed reserves	—
Proved undeveloped reserves as of December 31, 2023	24,821

Extensions and Discoveries

During 2023, no reserves were added from extension or discovery activities.

During 2022, we elected to participate in select development activities where third parties were engaged to complete the

development. Seven of these wells were in progress as of December 31, 2022, generating 8,832 MMcfe in proved

undeveloped reserves.

During 2021, no reserves were added from extension or discovery activities.

Purchase of Reserves in Place

During 2023, the 24,821 MMcfe of purchase of reserves in place were associated with the Tanos II acquisition and related to

four wells in progress that have been drilled and are awaiting hydraulic fracture stimulation.

During 2022, there were no purchases of proved undeveloped reserves in place.

During 2021, the 3,505 MMcfe of purchase of reserves in place were associated with the Tapstone Acquisition and related to

five wells that were under development as of December 31, 2021. We engaged third parties to complete this development

activity and during 2022 these were converted to proved developed reserves. Refer to Note 5 in the Notes to the Group

Financial Statements for additional information about acquisitions.

26	Diversified Energy Company PLC Annual Report and Form 20-F2023

Sales of Reserves in Place

During 2023, the 8,832 in sales of reserves in place were divested as part of the sale of 80% of the equity interest in DP Lion

Equity Holdco LLC in December 2023. Refer to Note 5 in the Notes to the Group Financial Statements for additional

information.

During 2022, there were no sales of reserves in place.

During 2021, there were no sales of reserves in place.

Developed and Undeveloped Acreage

The following table sets forth certain information regarding the total developed and undeveloped acreage in which we owned

an interest as of December 31, 2023. Developed acres are acres spaced or assigned to productive wells and do not include

undrilled acreage held by production under the terms of the lease. Undeveloped acres are acres on which wells have not been

drilled or completed to a point that would permit the production of commercial quantities of oil or natural gas, regardless of

whether such acreage contains proved reserves. Approximately 99.9% of our acreage was held by production at

December 31, 2023.

	Developed Acreage		Undeveloped Acreage		Total Acreage
	Gross(a)	Net(b)	Gross(a)	Net(b)	Gross(a)	Net(b)
As of December 31, 2023	5,600,383	3,039,447	8,005,314	5,519,159	13,605,697	8,558,606

(a)A gross acre is an acre in which a working interest is owned. The number of gross acres is the total number of acres in which a working

interest is owned.

(b)A net acre is deemed to exist when the sum of the fractional ownership working interests in gross acres equals one. The number of net acres

is the sum of the fractional working interests owned in gross acres expressed as whole numbers and fractions thereof.

The undeveloped acreage numbers presented in the table above have been compiled using best efforts to review and

determine acreage that is not currently drilled but may be available for drilling at the current time under certain circumstances.

Whether or not undrilled acreage may be drilled and thereafter produce economic quantities of oil or gas is related to many

factors which may change over time, including natural gas and oil prices, service vendor availability, regulatory regimes,

midstream markets, end user demand, and macro and micro financial conditions; the undeveloped acreage described herein is

presented without an opinion as to economic viability, as a result of the aforesaid factors. Additionally, it is noted that certain

formations on a land tract may be already developed while other formations are undeveloped.

The following table sets forth the number of total gross and net undeveloped acres as of December 31, 2023 that will expire in

2024, 2025 and 2026 unless production is established within the spacing units covering the acreage prior to the expiration

dates or unless such acreage is extended or renewed.

	Gross	Net
2024	5,404	663
2025	24,906	2,876
2026	2,869	87

Our primary focus is to operate our existing producing assets in a safe, efficient and responsible manner, however we also

assess areas subject to lease expiration for potential development opportunities when prudent. As of December 31, 2023, we

had no development plans other than the in-progress wells described above and therefore have not classified any other

potential undrilled locations on this acreage as proved undeveloped reserves.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	27

Preparation of Reserve Estimates

Our reserve estimates as of December 31, 2023 included in

this Annual Report & Form 20-F were independently

evaluated by our independent engineers, NSAI, in

accordance with petroleum engineering and evaluation

standards published by The Petroleum Resources

Management System jointly published by the Society of

Petroleum Engineers, the World Petroleum Council, the

American Association of Petroleum Geologists and the

Society of Petroleum Evaluation Engineers, as amended and

definitions and guidelines established by the SEC.

NSAI is a worldwide leader of petroleum property analysis

for industry and financial organizations and government

agencies. NSAI was founded in 1961 and performs

consulting petroleum engineering services under Texas

Board of Professional Engineers Registration No. F-2699.

Within NSAI, the technical persons primarily responsible for

auditing the estimates set forth in the NSAI reserves report

incorporated herein are Mr. Robert C. Barg and Mr. William

J. Knights. Mr. Barg, a Licensed Professional Engineer in the

State of Texas (No. 71658), has been practicing consulting

petroleum engineering at NSAI since 1989 and has over six

years of prior industry experience. He graduated from

Purdue University in 1983 with a Bachelor of Science

Degree in Mechanical Engineering. Mr. Knights, a Licensed

Professional Geoscientist in the State of Texas, Geology

(No. 1532), has been practicing consulting petroleum

geoscience at NSAI since 1991 and has over 10 years of prior

industry experience. He graduated from Texas Christian

University in 1981 with a Bachelor of Science Degree in

Geology in 1984 with a Master of Science Degree in

Geology. Both technical principals meet or exceed the

education, training and experience requirements set forth in

the Standards Pertaining to the Estimating and Auditing of

Oil and Gas Reserves Information promulgated by the

Society of Petroleum Engineers; both are proficient in

judiciously applying industry standard practices to

engineering and geoscience evaluations, as well as applying

SEC and other industry reserves definitions and guidelines.

Our internal staff of petroleum engineers and geoscience

professionals work closely with our independent reserve

engineers to ensure the integrity, accuracy and timeliness

of data furnished to our independent reserve engineers for

their reserve evaluation process. Our technical team

regularly meets with the independent reserve engineers to

review properties and discuss methods and assumptions

used to prepare reserve estimates. The reserve estimates

and related reports are reviewed and approved by our Vice

President of Reservoir Engineering. The Vice President of

Reservoir Engineering has been with the Group since 2018

and has 24 years of experience in petroleum engineering,

with over 20 years of experience evaluating natural gas and

oil reserves, and holds a Bachelor of Science in Petroleum

Engineering. Prior to joining the Group in 2018, our Vice

President of Reservoir Engineering served in various

reservoir engineering roles for public companies engaged in

the exploration and production operations, and is also a

member of the Society of Petroleum Engineers.

Estimation of Proved Reserves

Proved reserves are reserves which, by analysis of

geoscience and engineering data, can be estimated with

reasonable certainty to be economic1ally producible from a

given date forward from known reservoirs under existing

economic conditions, operating methods and government

regulations prior to the time at which contracts providing

the right to operate expires, unless evidence indicates that

renewal is reasonably certain. The term “reasonable

certainty” implies a high degree of confidence that the

quantities of oil or natural gas actually recovered will equal

or exceed the estimate. To achieve reasonable certainty, we

and the independent reserve engineers employed

technologies that have been demonstrated to yield results

with consistency and repeatability. The technologies and

economic data used in the estimation of our proved

reserves include, but are not limited to, well logs, geologic

maps and available downhole and production data,

micro-seismic data and well-test data.

Reserve engineering is and must be recognized as a

subjective process of estimating volumes of economically

recoverable oil and natural gas that cannot be measured in

an exact manner. The accuracy of any reserve estimate is a

function of the quality of available data and of engineering

and geological interpretation. As a result, the estimates of

different engineers often vary. In addition, the results of

drilling, testing and production may justify revisions of such

estimates. Accordingly, reserve estimates often differ from

the quantities of natural gas, NGLs and oil that are

ultimately recovered. Estimates of economically

recoverable natural gas, NGLs and oil and of future net cash

flows are based on a number of variables and assumptions,

all of which may vary from actual results, including geologic

interpretation, prices and future production rates and costs.

See Risk Factors for additional information.

28	Diversified Energy Company PLC Annual Report and Form 20-F2023

Productive Wells

Productive wells consist of producing wells, wells capable of production and wells awaiting connection to production facilities.

Gross wells are the total number of producing wells in which we have an interest, operated and non-operated, and net wells

are the sum of our fractional working interest owned in gross wells. The following table summarizes our productive natural gas

and oil wells as of December 31, 2023.

	As of December 31, 2023
Natural gas wells	71,471
Oil wells	3,044
Total gross productive wells	74,515
Natural gas wells	59,226
Oil wells	1,413
Total net productive wells	60,639	As of December 31, 2023(a)
---	---
Total gross in progress wells	4.0
Total net in progress wells	3.8

(a)Comprised of wells in the Central Region.

Exploratory and Development Drilling Activities

Information regarding our drilling and development activities is set forth below:

	Development
	Productive Wells		Dry Wells		Total
Year	Gross	Net	Gross	Net	Gross	Net
2023	4	4	—	—	4	4
2022	5	2	—	—	5	2
2021	—	—	—	—	—	—

We drilled no exploratory wells (productive or dry) during the years ended December 31, 2023, 2022 and 2021.

During 2021, we completed the Tapstone Acquisition, which included five wells in the Central Region that were under

development by Tapstone as of December 31, 2021. We engaged third parties to complete this development activity, however

they remained in progress as of December 31, 2021.

During 2022, we completed the development of the five wells referenced in the preceding paragraph that had been under

development as of December 31, 2021. We then elected to participate in seven development opportunities on a non-

operating basis in our Appalachian Region. All seven of the Appalachian development wells remained in progress as of

December 31, 2022.

During 2023, we completed the development of two of the seven Appalachian wells that were under development as of

December 31, 2022. The remaining five Appalachian wells were divested in connection with the sale of 80% of the equity

interest in DP Lion Equity Holdco LLC in December 2023. On March 1, 2023, we also completed the Tanos II acquisition, which

included five wells in the Central Region that were under development at the date of acquisition. During 2023, we completed

one of these five wells. As of December 31, 2023, four Central Region development wells remain in progress. Refer to Note 5 in

the Notes to the Group Financial Statements for additional information regarding the sale of equity interest in DP Lion Equity

Holdco LLC.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	29

Production Volumes, Average Sales Prices and Operating Costs

	Year Ended
	December 31, 2023	December 31, 2022	December 31, 2021
Production
Natural Gas (MMcf)	256,378	255,597	234,643
NGLs (MBbls)	5,832	5,200	3,558
Oil (MBbls)	1,377	1,554	592
Total production (MMcfe)	299,632	296,121	259,543
Average realized sales price
(excluding impact of derivatives settled in cash)
Natural gas (Mcf)	$2.17	$6.04	$3.49
NGLs (Bbls)	24.23	36.29	32.53
Oil (Bbls)	75.46	89.85	65.26
Total (Mcfe)	$2.68	$6.33	$3.75
Average realized sales price
(including impact of derivatives settled in cash)
Natural gas (Mcf)	$2.86	$2.98	$2.36
NGLs (Bbls)	26.05	19.84	15.52
Oil (Bbls)	68.44	72.00	71.68
Total (Mcfe)	$3.27	$3.30	$2.51
Operating costs per Mcfe
LOE(a)	$0.71	$0.62	$3.31
Production taxes(b)	0.21	0.25	0.53
Midstream operating expense(c)	0.23	0.24	1.42
Transportation expense(d)	0.32	0.40	1.28
Total operating expense per Mcfe	$1.47	$1.51	$6.54

(a)LOE is defined as the sum of employee and benefit expenses, well operating expense (net), automobile expense and insurance cost.

(b)Production taxes include severance and property taxes. Severance taxes are generally paid on produced natural gas, NGLs and oil

production at fixed rates established by federal, state or local taxing authorities. Property taxes are generally based on the taxing

jurisdictions’ valuation of our natural gas and oil properties and midstream assets.

(c)Midstream operating expenses are daily costs incurred to operate our owned midstream assets inclusive of employee and benefit expenses.

(d)Transportation expenses are daily costs incurred from third-party systems to gather, process and transport our natural gas, NGLs and oil.

Significant Fields

The Group operates in four primary fields: (i) Appalachia, which is comprised of the stacked Marcellus and Utica shales and

other conventional formations (that form our Central Region) (ii) East Texas and Louisiana, which consists of the stacked

Cotton Valley, Haynesville, and Bossier shales, (iii) the Barnett Shale and (iv) the Midcontinent region, in North Texas and

Oklahoma, which also consists of various stacked plays. The following table presents production for the Group’s Appalachian

region, which is considered significant, or greater than 15% of the Group’s total proved reserves, for the periods presented.

	Year Ended
APPALACHIA	December 31, 2023	December 31, 2022	December 31, 2021
Production
Natural Gas (MMcf)	167,930	180,194	201,635
NGLs (MBbls)	3,018	2,810	2,690
Oil (MBbls)	394	423	446
Total production (MMcfe)	188,402	199,592	220,451
30	Diversified Energy Company PLC Annual Report and Form 20-F2023
---	---

Customers

Our production is generally sold on month-to-month contracts at prevailing market prices.

During the year ended December 31, 2023, no customers individually comprised more than 10% of total revenues.

During the year ended December 31, 2022, no customers individually comprised more than 10% of total revenues.

During the year ended December 31, 2021, two customers individually comprised more than 10% of total revenues,

representing 22% of consolidated revenues.

Because alternative purchasers of oil and natural gas are readily available, we believe that the loss of any of these purchasers

would not result in a material adverse effect on our ability to sell future oil and natural gas production. In order to mitigate

potential exposure to credit risk, we may require from time to time for our customers to provide financial security.

Delivery Commitments

We have contractually agreed to deliver firm quantities of natural gas to various customers, which we expect to fulfill with

production from existing reserves. We regularly monitor our proved developed reserves to ensure sufficient availability to

meet these commitments. The following table summarizes our total gross commitments, compiled using best estimates based

on our sales strategy, as of December 31, 2023.

	Natural gas (MMcf)
2024	70,769
2025	16,658
2026	—
Thereafter	360,114

Transportation and Marketing

Diversified Energy Marketing, LLC, our wholly owned

marketing subsidiary, specializes in commodity marketing,

asset optimization, producer services and the strategic

management of our transportation portfolio. Our mission

extends to enhancing operational efficiency and

profitability, leveraging market insights, operational

expertise, strategic asset management and the right sizing

of our contractual transport assets to ensure flow reliability

and access to various markets.

Our comprehensive suite of services encompasses the

marketing of natural gas, NGL’s and oil, risk management,

logistical support and the strategic management of

transportation agreements. This approach is designed to

maximize market presence, financial outcomes, ensure

consistent product flow and capitalize on strengthening

markets through our transportation infrastructure and

vertically integrated midstream systems. Our midstream

infrastructure and strategic arrangements enable us to

access high-demand markets, notably in the U.S. Gulf Coast

region, while leveraging low cost transportation in

Appalachia. The synergistic nature of our asset base allows

for access to advantageous pricing year-round and flow

assurance with minimal firm transportation agreements. As

of December 31, 2023, our transportation arrangements

provide access to 515 MMcfepd of takeaway capacity.

As a dedicated arm of the Group, our marketing team

ensures our operations and strategies are closely aligned

with our broader goals. With a team of experienced

professionals and a deep understanding of the energy

market’s nuances, we are committed to delivering value and

reliability to our stakeholders. We navigate through the

industry’s complexities to achieve operation excellence.

Competition

Our marketing activities compete with numerous other

companies offering the same services, many of which

possess larger financial and other resources than we have.

Some of these competitors are other producers and

affiliates of companies with extensive pipeline systems that

are used for transportation from producers to end users.

Other factors affecting competition are the cost and

availability of alternative fuels, the level of consumer

demand and the cost of and proximity to pipelines and

other transportation facilities. We believe that our ability to

compete effectively within the marketing segment in the

future depends upon establishing and maintaining strong

relationships with customers.

Seasonality

Demand for natural gas and oil generally decreases during

the spring and fall months and increases during the summer

and winter months. However, seasonal anomalies and

consumers’ procurement initiatives can also lessen seasonal

demand fluctuations. Seasonal anomalies can increase

competition for equipment, supplies and personnel and

can lead to shortages and increase costs or delay

our operations.

Title to Properties

We believe that we have satisfactory title to substantially all

of our active properties in accordance with standards

generally accepted in the oil and natural gas industry. Our

properties are subject to customary royalty and overriding

royalty interests, certain contracts relating to the

exploration, development, operation and marketing of

production from such properties, consents to assignment

and preferential purchase rights, liens for current taxes,

applicable laws and other burdens, encumbrances and

irregularities in title, which we believe do not materially

interfere with the use of or affect the value of such

properties. Prior to acquiring producing wells, we endeavor

to perform a title investigation on an appropriate portion of

the properties that is thorough and is consistent with

standard practice in the natural gas and oil industry.

Generally, we conduct a title examination and perform

curative work with respect to significant defects that we

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	31

identify on properties that we operate. We believe that we

have performed reasonable and protective title reviews

with respect to an appropriate cross-section of our

operated natural gas and oil wells.

GOVERNMENT REGULATION

General

Our operations in the United States are subject to various

federal, state and local (including county and municipal

level) laws and regulations. These laws and regulations

cover virtually every aspect of our operations including,

among other things: use of public roads; construction of

well pads, impoundments, tanks and roads; pooling and

unitizations; water withdrawal and procurement for well

stimulation purposes; wastewater discharge, well drilling,

casing and hydraulic fracturing; stormwater management;

well production; well plugging; venting or flaring of natural

gas; pipeline construction and the compression and

transportation of natural gas and liquids; reclamation and

restoration of properties after natural gas and oil operations

are completed; handling, storage, transportation and

disposal of materials used or generated by natural gas and

oil operations; the calculation, reporting and payment of

taxes on natural gas and oil production; and gathering of

natural gas production. Various governmental permits,

authorizations and approvals under these laws and

regulations are required for exploration and production as

well as midstream operations. These laws and regulations,

and the permits, authorizations and approvals issued

pursuant to such laws and regulations, are intended to

protect, among other things: air quality; ground water and

surface water resources, including drinking water supplies;

wetlands; waterways; protected plants and wildlife; natural

resources; and the health and safety of our employees and

the communities in which we operate.

We endeavor to conduct our operations in compliance with

all applicable U.S. federal, state and local laws and

regulations. However, because of extensive and

comprehensive regulatory requirements against a backdrop

of variable geologic and seasonal conditions,

non-compliance during operations can occur. Certain

non-compliance may be expected to result in fines or

penalties, but could also result in enforcement actions,

additional restrictions on our operations, or make it more

difficult for us to obtain necessary permits in the future. The

possibility exists that new legislation or regulations may be

adopted which could have a significant impact on our

operations or on our customers’ ability to use our natural

gas, natural gas liquids and oil, and may require us or our

customers to change their operations significantly or incur

substantial costs.

Environmental Laws

Many of the U.S. laws and regulations referred to above are

environmental laws and regulations, which vary according

to the jurisdiction in which we conduct our operations. In

addition to state or local laws and regulations, our

operations are also subject to numerous federal

environmental laws and regulations. Below is a discussion

of some of the more significant federal laws and regulations

applicable to us and our operations.

Clean Air Act

The federal Clean Air Act and associated Federal and state

regulations regulate air emissions through permitting and/

or emissions control requirements. These regulations affect

the entire value chain from oil and natural gas production,

to gathering, to processing, to transmission and storage,

and then to distribution operations. Various equipment and

activities in our assets are subject to regulation, including

compressors, engines, dehydrators, storage tanks,

pneumatic devices, fugitive components, and blowdowns.

We obtain permits, typically from state or local authorities,

or document exemptions necessary to authorize these

activities. Further, we are required to obtain pre-approval

for construction or modification of certain facilities, and/or

to use specific equipment, technologies or best

management practices to control emissions. Some states

also require a separate operating permit to be obtained for

on-going operations.

Federal and state governmental agencies continue to

review and revise the air quality regulations affecting oil

and natural gas activities, and further regulation could

increase our cost or otherwise affect our ability to produce.

For instance, on March 7, 2024, the U.S. Environmental

Protection Agency (“EPA”) finalized New Source

Performance Standard Subpart OOOOb (NSPS OOOOb) for

new, modified, and reconstructed sources after

December 6, 2022, and Emissions Guideline Subpart

OOOOc (EG OOOOc) for sources existing prior to

December 6, 2022. Most provisions of NSPS OOOOb take

effect immediately while certain requirements have phase-

in periods. EG OOOOc requires individual states to

incorporate similar provisions into their regulations (or rely

upon EPA’s model requirements) and will require

approximately five years to be implemented. The affected

source categories under OOOOb and OOOOc include well

completions, fugitive emissions, liquids unloading, process

controllers, process pumps, storage vessels, and

associated gas.

EPA has also recently proposed two interrelated

regulations. On August 1, 2023, EPA proposed revisions to

the greenhouse gas reporting rule for the oil and natural

gas industry to change the calculation methodology to be

primarily based on actual emission measurements rather

than emission factors. These changes facilitate the

implementation of a methane fee under the Waste Emission

Charge (WEC) rule which was proposed on

January 26, 2024. Both rules are expected to be finalized

by August 2024 as required by the Inflation Reduction Act

(IRA) of 2022. Under the WEC rule, reporters would be

subject to a fee beginning in 2025 at $900 per ton of

methane emissions that exceed thresholds prescribed

under the rule. These methane emissions would be based

on those reported under the greenhouse gas reporting rule.

Clean Water Act

The federal Clean Water Act (“CWA”) and corresponding

state laws affect our operations by regulating storm water

or other discharges of substances, including pollutants,

sediment, and spills and releases of oil, brine and other

substances, into surface waters, and in certain instances

imposing requirements to dispose of produced wastes and

other oil and gas wastes at approved disposal facilities. The

discharge of pollutants into jurisdictional waters is

prohibited, except in accordance with the terms of a permit

issued by the EPA, the U.S. Army Corps of Engineers, or a

delegated state agency. These permits require regular

monitoring and compliance with effluent limitations, and

include reporting requirements. Federal and state

regulatory agencies can impose administrative, civil and/or

criminal penalties for non-compliance with discharge

permits or other requirements of the CWA and analogous

state laws and regulations.

32	Diversified Energy Company PLC Annual Report and Form 20-F2023

Endangered Species and Migratory Birds

The Endangered Species Act and related state laws

regulations protect plant and animal species that are

threatened or endangered. The Migratory Bird Treaty Act

and the Bald and Golden Eagle Protection Act provides

similar protections to migratory birds and bald and golden

eagles, respectively. Some of our operations are located in

areas that are or may be designated as protected habitats

for endangered or threatened species, or in areas where

migratory birds or bald and golden eagles are known to

exist. Laws and regulations intended to protect threatened

and endangered species, migratory birds, or bald and

golden eagles could have a seasonal impact on our

construction activities and operations. New or additional

species that may be identified as requiring protection or

consideration could also lead to delays in obtaining permits

and/or other restrictions, including operational restrictions.

Safety of Gas Transmission and

Gathering Pipelines

Natural gas pipelines serving our operations are subject to

regulation by the U.S. Department of Transportation’s

PHMSA pursuant to the NGPSA, as amended by the Pipeline

Safety Act of 1992, the Accountable Pipeline Safety and

Partnership Act of 1996, the PSIA, the Pipeline Inspection,

Protection, Enforcement and Safety Act of 2006, and the

2011 Pipeline Safety Act. The NGPSA regulates safety

requirements in the design, construction, operation and

maintenance of natural gas pipeline facilities, while the PSIA

establishes mandatory inspections for all U.S. oil and natural

gas transmission pipelines in high-consequence areas.

Additionally, certain states, such as West Virginia, also

maintain jurisdiction over intrastate natural gas lines. In

October 2019, PHMSA finalized the first of three rules that,

collectively, are referred to as the natural gas “Mega Rule.”

The first rule imposed additional safety requirements on

natural gas transmission pipelines, including maximum

operating pressure and integrity management near HCAs

for onshore gas transmission pipelines. PHMSA finalized the

second rule extending federal safety requirements to

onshore gas gathering pipelines with large diameters and

high operating pressures in November 2021. PHMSA

published the final of the three components of the Mega

Rule in August 2022, which took effect in May 2023. The

final rule applies to onshore gas transmission pipelines,

clarifies integrity management regulations, expands

corrosion control requirements, mandates inspection after

extreme weather events, and updates existing repair

criteria for both HCA and non-HCA pipelines. Finally,

PHMSA published a Notice of Proposed Rulemaking

regarding more stringent gas pipeline leak detection and

repair requirements to reduce natural gas emissions on May

18, 2023. The adoption of laws or regulations that apply

more comprehensive or stringent safety standards could

increase the expenses we incur for gathering service.

Resource Conservation and Recovery Act

The federal Resource Conservation and Recovery Act

(“RCRA”) and corresponding state laws and regulations

impose requirements for the management, treatment,

storage and disposal of hazardous and non-hazardous

wastes, including wastes generated by our operations.

Drilling fluids, produced waters and most of the other

wastes associated with the exploration, development and

production of natural gas and oil are currently regulated

under RCRA’s solid (non-hazardous) waste provisions.

However, legislation has been proposed from time to time,

and various environmental groups have filed lawsuits, that,

if successful, could result in the reclassification of certain

natural gas and oil exploration and production wastes as

“hazardous wastes,” which would make such wastes subject

to much more stringent handling, disposal and clean-up

requirements. A change in the RCRA exclusion for drilling

fluids, produced waters and related wastes could result in

an increase in our costs to manage and dispose of

generated wastes, which could have a material adverse

effect on the industry as well as on our results of operations

and financial position.

Comprehensive Environmental Response,

Compensation, and Liability Act

The Comprehensive Environmental Response,

Compensation, and Liability Act (“CERCLA” or

“Superfund”) imposes joint and several liability for costs of

investigation and remediation, and for natural resource

damages without regard to fault or the legality of the

original conduct, on certain classes of persons with respect

to the release into the environment of substances

designated under CERCLA as hazardous substances. These

classes of persons, so-called potentially responsible parties

(“PRP”), include the current and past owners or operators

of a site where the release occurred and anyone who

disposed, transported, or arranged for the disposal,

transportation, or treatment of a hazardous substance

found at the site. CERCLA also authorized the EPA and, in

some instances, third parties to take actions in response to

threats to public health or the environment, and to seek to

recover from the PRPs the costs of such action. Many

states, including states in which we operate, have adopted

comparable state statutes.

Although CERCLA generally exempts “petroleum” from

regulation, in the course of our operations we have

generated and will generate wastes that may fall within

CERCLA’s definition of hazardous substances, and may

have disposed of these wastes at disposal sites owned and

operated by others. We may also be the owner or operator

of sites on which hazardous substances have been released.

In the event contamination is discovered at a site on which

we are or have been an owner or operator, or to which we

have sent hazardous substances, we could be jointly and

severally liable for the costs of investigation and

remediation and natural resource damages. Further, it is not

uncommon for neighboring landowners and other third

parties to file claims for personal injury and property

damage allegedly caused by hazardous substances or other

pollutants released into the environment.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	33

Oil Pollution Act

The primary federal law related to oil spill liability is the Oil

Pollution Act (“OPA”), which amends and augments oil spill

provisions of the Clean Water Act and imposes certain

duties and liabilities on certain “responsible parties” related

to the prevention of oil spills and damages resulting from

such spills in or threatening waters of the United States or

adjoining shorelines. A liable “responsible party” includes

the owner or operator of a facility, vessel or pipeline that is

a source of an oil discharge or that poses the substantial

threat of discharge. OPA assigns joint and several liability,

without regard to fault, to each liable party for oil removal

costs and a variety of public and private damages.

Although defenses exist to the liability imposed by OPA,

they are limited. In the event of an oil discharge or

substantial threat of discharge, we may be liable for costs

and damages.

Regulation of the Sale and Transportation of

Natural Gas, NGLs and Oil

The transportation and sale, or resale, of natural gas in

interstate commerce are regulated by the Federal Energy

Regulatory Commission (“FERC”) under the Natural Gas

Act of 1938, the Natural Gas Policy Act of 1978, and

regulations issued under those statutes. FERC regulates

interstate natural gas transportation rates and terms and

conditions of service, which affects the marketing of natural

gas that we produce, as well as the revenues we receive for

sales of our natural gas. FERC regulations require that rates

and terms and conditions of service for interstate service

pipelines that transport crude oil and refined products and

certain other liquids be just and reasonable and must not be

unduly discriminatory or confer any undue preference upon

any shipper. FERC regulations also require interstate

common carrier petroleum pipelines to file with FERC and

publicly post tariffs stating their interstate transportation

rates and terms and conditions of service.

Section 1(b) of the Natural Gas Act exempts natural gas

gathering facilities from regulation by FERC. However, the

distinction between federally unregulated gathering

facilities and FERC regulated transmission facilities is a

fact-based determination, and the classification of facilities

is the subject of ongoing litigation. We own certain natural

gas pipeline facilities that we believe meet the traditional

tests FERC has used to establish a pipeline’s primary

function as “gathering,” thus exempting it from the

jurisdiction of FERC under the Natural Gas Act.

Intrastate natural gas transportation is also subject to

regulation by state regulatory agencies. The basis for

intrastate regulation of natural gas transportation and the

degree of regulatory oversight and scrutiny given to

intrastate natural gas pipeline rates and services varies from

state to state. Like the regulation of interstate

transportation rates, the regulation of intrastate

transportation rates affects the marketing of natural gas

that we produce, as well as the revenues we receive for

sales of our natural gas.

FERC regulates the transportation of oil and NGLs on

interstate pipelines under the provisions of the Interstate

Commerce Act, the Energy Policy Act of 1992 and

regulations issued under those statutes. Intrastate

transportation of oil, NGLs and other products is dependent

on pipelines whose rates, terms and conditions of service

are subject to regulation by state regulatory bodies under

state statutes.

Natural gas, NGLs and crude oil prices are currently

unregulated, but Congress historically has been active in

the area of natural gas, NGLs and crude oil regulation. We

cannot predict whether new legislation to regulate sales

might be enacted in the future or what effect, if any, any

such legislation might have on our operations.

Health and Safety Laws

Our operations are subject to regulation under the federal

Occupational Safety and Health Act (“OSHA”) and

comparable state laws in some states, all of which regulate

health and safety of employees at our operations.

Additionally, OSHA’s hazardous communication standard,

the EPA community right-to-know regulations under Title III

of the federal Superfund Amendment and Reauthorization

34	Diversified Energy Company PLC Annual Report and Form 20-F2023

Act and comparable state laws require that information be

maintained about hazardous materials used or produced by

our operations and that this information be provided to

employees, state and local governments and the public.

Climate Change Laws and Regulations

Climate change continues to be a legislative and regulatory

focus. There are a number of proposed and recently-

enacted laws and regulations at the international, federal,

state, regional and local level that seek to limit greenhouse

gas emissions, and such laws and regulations that restrict

emissions could increase our costs should the requirements

necessitate the installation of new equipment or the

purchase of emission allowances. For example, the Inflation

Reduction Act, which was signed into law in August 2022,

includes a “methane fee” that is expected to be imposed

beginning with emissions reported for calendar year 2024.

In addition, the current U.S. administration has proposed

more stringent methane pollution limits for new and

existing gas and oil operations. These laws and regulations

could also impact our customers, including the electric

generation industry, making alternative sources of energy

more competitive and thereby decreasing demand for the

natural gas and oil we produce. Additional regulation could

also lead to permitting delays and additional monitoring

and administrative requirements, in turn impacting

electricity generating operations.

At the international level, President Biden has recommitted

the United States to the UN-sponsored “Paris Agreement,”

for nations to limit their greenhouse gas emissions through

non-binding, individually-determined reduction goals every

five years after 2020. In April 2021, President Biden

announced a goal of reducing the United States’ emissions

by 50 – 52% below 2005 levels by 2030. In November 2021,

the international community gathered in Glasgow at the

26th Conference of the Parties to the UN Framework

Convention on Climate Change, during which multiple

announcements were made, including a call for parties to

eliminate certain fossil fuel subsidies and pursue further

action on non-carbon dioxide greenhouse gases. In a

related gesture, the United States and the European Union

jointly announced the launch of the “Global Methane

Pledge,” which aims to cut global methane pollution by at

least 30% by 2030 relative to 2020 levels, including “all

feasible reductions” in the energy sector. Such

commitments were re-affirmed at the 27th Conference of

the Parties in Sharm El Sheikh. Although it is not possible at

this time to predict how legislation or new regulations that

may be adopted pursuant to the Paris Agreement to

address greenhouse gas emissions would impact our

business, any such future laws and regulations imposing

reporting obligations on, or limiting emissions of

greenhouse gases from, our equipment and operations

could require us to incur costs to implement such measures

associated with our operations.

In addition, activists concerned about the potential effects

of climate change have directed their attention at sources

of funding for energy companies, which has resulted in

certain financial institutions, funds and other sources of

capital restricting or eliminating their investment in natural

gas and oil activities. Ultimately, this could make it more

difficult to secure funding for exploration and production

activities. Litigation risks are also increasing, as a number of

cities and other local governments have sought to bring

suits against the largest oil and natural gas exploration and

production companies in state or federal court, alleging,

among other things, that such companies created public

nuisances by producing fuels that contributed to global

climate change effects, such as rising sea levels, and

therefore are responsible for roadway and infrastructure

damages, or alleging that the companies have been aware

of the adverse effects of climate change for some time but

defrauded their investors by failing to adequately disclose

those impacts.

Additionally, the SEC published its long-awaited climate

rule in early March 2024, requiring the disclosure of a range

of climate-related risks and financial impacts. We are

currently assessing this rule, and at this time we cannot

predict the costs of implementation or any potential

adverse impacts for either the Group or our customers

resulting from the rule. Additionally, enhanced climate

disclosure requirements could accelerate the trend of

certain stakeholders and lenders restricting or seeking more

stringent conditions with respect to their investments in

certain carbon-intensive sectors.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	35

A Letter from Our Senior

VP of Sustainability

“
We remain focused on environmental<br><br>stewardship as well as meaningful and<br><br>effective employee and community<br><br>engagement, delivered with an intentional<br><br>adherence to a strong foundation of<br><br>good governance.”

Sustainability Review

Thank you for your interest in Diversified’s sustainability

journey, which we believe aligns with not only our

stewardship business model but also value creation for our

stakeholders. I am pleased to share this annual review of

the successes and challenges on our 2023 journey,

inclusive of updates on key environmental, social and

governance objectives.

Of primary importance and consideration to our

sustainability efforts is our environmental impact, and

specifically our emissions footprint. During 2023, our well

tenders and midstream personnel remained focused on

progressing voluntary leak detection and repairs and other

emission reduction initiatives, while our environmental

teams were equally focused on identifying, researching and

field testing a multitude of emission abatement or reduction

technology alternatives for consideration in our near- and

long-term emissions reduction roadmap in order to achieve

our stated 2040 net zero goal.

These diligent efforts benefited the Group alongside both

our long-standing, proven Smarter Asset Management

optimization and efficiency improvement actions and the

increasingly demonstrable environmental and risk

mitigation wins from our multiple remote monitoring Gas

Control and Integrated Operating centers.

As we have said before, we are committed to reporting

transparently on our performance, even when it falls short

of our expectations. For example, our 2023 personal safety

performance did not meet our high standards as it relates

specifically to Total Recordable Incident Rate which

increased year-over-year as a result of an increase in

reported incidents. While our OneDEC corporate culture

and number one daily priority of ‘Safey-No Compromises’

remains steadfast, what is changing is our approach of how

improvement is best achieved.

Much like we did previously when liquids spill rates were

not meeting our expectations, we have already begun

dedicating focused time, attention and manpower to this

matter to ascertain how best to move forward with making

improvements. Having identified accountability as a key

contributor to this shortfall, we have already begun

addressing accountability with both field leadership and

staff. We look forward to sharing more about these actions

as we work towards delivering on the high expectations we

set for ourselves.

During 2023, we also updated our periodic materiality

assessment with both internal and external stakeholders,

the results of which reflected that employee safety remains

our top priority across the stakeholder groups. These

results reinforce our desire and drive to promptly and

appropriately address all matters related to employee

safety, beginning with our work thus far on TRIR.

We remain committed to setting appropriate objectives

related to our sustainability journey and reporting

transparently on the same. This priority is being recognized

in the marketplace as evidenced by our 2022 Sustainability

Report receiving the ESG Report of the Year award from

ESG Awards 2023 and that same report driving an

improved MSCI ESG rating score to Leadership status.

Furthermore, the Oil and Gas Methane Partnership 2.0 has

awarded our emissions reduction roadmap a Gold Standard

Pathway designation for the second consecutive year,

signaling the validity of our environmental stewardship

model and transparency thereof.

2023 was another successful year in many respects, but we

will not stop there as we have much more we want, and

need, to do to bolster our long-term sustainability. We will

remain focused on environmental stewardship (PLANET) as

well as meaningful and effective employee and community

engagement (PEOPLE), delivered with an intentional

adherence to a strong foundation of good governance

(PRINCIPLES).

The best is yet to come!

Teresa B. Odom

Senior Vice President - Sustainability

March 19, 2024

Additional information on our climate, environmental, safety and

social performance will be available in our separate sustainability

communications on our website at www.div.energy.

36	Diversified Energy Company PLC Annual Report and Form 20-F2023

Our Strategy Supports Sustainability

Our sustainability strategy is centered around prudent risk management, asset integrity, employee safety, environmental protection, and emissions reduction. From the wellhead to the boardroom, we are committed to our role as responsible stewards of the natural resources we manage, the people we employ and the environment in which we operate. We strive to adhere to quality operating standards with a strong focus on the environment, the health and safety of employees and positive engagement with our local communities. We believe our efforts to connect the meaningful and differentiated attributes associated with our natural gas will increasingly be recognized by the market as value is progressively placed on highly responsible operators of natural gas assets. We are committed to addressing key climate and environmental issues for our PLANET and likewise relevant social issues for the PEOPLE across our operations, and doing so with a constant focus on the values and PRINCIPLES under which we were founded and continue to operate.

Commitment to Leadership and Transparency

Responsible stewardship and sustainability go hand-in-hand

and are at the core of our operations. Through sustainability

leadership and our unique business model, we

systematically strengthen our performance and execute on

our sustainability plans and commitments. We work

diligently to foster a culture of stewardship and

transparency, and a key aspect of our approach is to seek

stakeholder input while also keeping them apprised of

progress against our sustainability ambitions.

In 2023, we updated our periodic, formal multi-stakeholder

materiality assessment, utilizing our prior materiality

assessment, stakeholder outreach and peer benchmarking

to identify 29 relevant topics spread among eight key

clusters that include health and safety, climate change,

environmental management, resource management,

socio-economic value creation, our employees, suppliers

and partners, and risks and compliance.

We engaged both internal stakeholders such as Board

members and employees at all levels and locations as well

as external stakeholders across our value chain such as

equity and debt investors, financial service providers, trade

associations, customers, contractors and suppliers. The

assessment was conducted via a third-party, anonymous

online survey and the results were then compiled for

distribution and review by management and the

Sustainability & Safety Committee.

Among the relevant topics, the survey reflected that eight

topics of the top ten shared highest materiality among both

internal and external stakeholders, including the following:

—Employee safety

—Driver safety

—Cybersecurity

—Legal compliance

—Accident prevention

—Ethical behavior

—Access to funding

—Incident management

Survey over survey, the protection and safety of employees

continues to be a top priority while cybersecurity and

related data protection protocols was the single largest

upward mover and is now a top five priority for internal

stakeholders and likewise a top ten priority for external

stakeholders. Safe and efficient asset retirement fell out of

the top five relevance for both internal and external

stakeholders, though remains a top ten priority for external

stakeholders. For external stakeholders, emissions control

and reductions also fell in relevance, settling among their

top 20 material topics. Importantly, all of these issues

should not be viewed in isolation as they are increasingly

interconnected and can often impact each other.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	37

Our Approach to Sustainability

Our approach to sustainability encompasses consideration

of our climate, environmental and social impacts as well as

our responsibility to conduct business in accordance with

the highest standards of governance. These topics remain

front of mind as we proudly accept the responsibility and

privilege to be part of the solution to the significant

challenges of our country’s energy, climate and economic

security. To that end,

—by providing a reliable supply of abundant domestic

energy from assets that have a significantly smaller

environmental footprint than newly drilled wells, we

support our nation’s energy security.

—by making investments and implementing measures to

reduce emissions at the facilities we acquire, producing

differentiated natural gas through our industry-

recognized emissions detection, measurement and

mitigation processes, and retiring orphan wells for

several states, we are part of the solution for

climate security.

—by providing an affordable and sustainable domestic

energy supply while also providing both direct and

indirect employment, paying mineral royalties, and

supporting tax revenues for the communities where we

operate, we are grateful to be contributing to our

country’s economic security.

LIFE-CYCLE STEWARDSHIP

With a unique business model that reflects growth through

acquisitions and an operating strategy that embodies

stewardship of our natural resources and the environment,

we understand the importance of a full, life-cycle focus on

the assets we manage. As such, we have established an

employee-driven, data-focused sustainability program

which integrates sustainability considerations and actions

throughout our assets’ life cycles, beginning with pre-

acquisition diligence screening and continuing until we

safely and permanently retire the acquired assets at the end

of their productive lives. These considerations are the very

heart of the operational priorities that collectively represent

our proven SAM program, which is designed to increase

efficiencies, reduce fugitive greenhouse gas (“GHG”)

emissions, and deliver improvements in production at

existing facilities.

38	Diversified Energy Company PLC Annual Report and Form 20-F2023

SUPPORTING LONG-TERM SUSTAINABILITY

We view sustainability through the lens of creating

long-term sustainable value for our stakeholders while

ensuring our daily actions contribute to a sustainable

environment and planet for society at large. We

demonstrate this focus when we align our stewardship-

focused business model and OneDEC culture with our

commitment to continuously identify, improve and monitor

our sustainability actions, as evidenced through our setting

and tracking of relevant and measurable targets.

These targets include, in part, our previously disclosed

Scope 1 methane emissions intensity reductions of 30% and

50% by 2026 and 2030, respectively, as compared to our

2020 baseline. Ongoing human and financial capital

investments across our asset portfolio, aimed largely at

methane reduction through leak detection and repair

“(LDAR”) efforts and conversion of natural gas-driven

pneumatic devices to compressed air, contributed to a 33%

reduction in reported methane emissions intensity for

year-end 2023, as further discussed on page 56.

While this accomplishment achieves our 2030 reduction

target seven years earlier than anticipated, we continue to

seek opportunities to further reduce our methane footprint.

In light of forthcoming environmental regulations that may

add new source categories of reported emissions, we will

evaluate those regulations as we consider new interim

targets. Even so, our year-over-year focused efforts and

life-cycle stewardship actions will continue to play a vital

role in keeping us on track toward our stated goal of Scope

1 and 2 net zero absolute GHG emissions by 2040.

In addition to our own guiding values for sustainability

management, we also utilize the United Nations’

Sustainable Development Goals (“SDGs”), which call on

individuals, corporations and governments to work

together towards the ultimate, unified goal of creating a

better and more sustainable future for all citizens globally.

At Diversified, we challenge ourselves to consider these

topics and more when we effectuate our business model,

corporate strategy, sustainability commitments, daily

operations, and risk management practices. We believe our

OneDEC approach supports important contributions to the

SDGs illustrated below, and we’ve identified several other

SDGs to which our business model aligns yet also provides

added opportunities for us to make continuous

improvement and contribution.

Task Force on Climate-Related

Financial Disclosures (“TCFD”)

The report is consistent with the recommendations of the

TCFD, with the exception of Scope 3 emissions, as noted

below, and in line with the Financial Conduct Authority’s

Listing Rule 9.8.6 requirement. The report also reflects the

guidance provided in Section C of the TCFD Annex, entitled

“Guidance for All Sectors” and Section E of the TCFD

Annex, entitled “Supplemental Guidance for Non-Financial

Groups”, related to the Energy sector. We are in the

process of developing a Scope 3 inventory in line with

existing protocols and evolving market expectations and

aim to report Scope 3 emissions for the 2024 year end.

While we remain focused on emissions reductions where we

have the most control, and thus are making good progress

in decarbonizing our own operations, we recognize that the

GHG emissions associated with our value chain are

proportionately greater than non-energy producing

companies as our Scope 3 emissions are associated mostly

with the end-use of our products. Therefore, we seek to

identify GHG reduction opportunities from our upstream

and downstream supply chains. We also evaluate initiatives,

including renewable natural gas and carbon capture and

storage projects which, in the longer-term, would allow us

to mitigate or offset some or all of our Scope 1 and

2 GHG emissions.

GOVERNANCE<br><br>EMBEDDING SUSTAINABILITY ACROSS THE<br><br>ORGANIZATION

Our Board of Directors (“Board” or “Directors”) continues

to take a hands-on approach to identifying, assessing and

managing climate-related risks and seeking new

commercial opportunities from an energy transition, such as

alternative uses for our wellbores. The processes by which

the Board does this are fully integrated into our Board

calendar and our governance procedures. Climate-related

topics were included in discussions at each of the six

regular Board meetings held throughout 2023.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	39

The Directors receive regular briefings at Board meetings

on applicable climate matters from the Executive team as

well as the Chair of the Sustainability & Safety Committee.

From time to time the Board also receives training or

briefings from external third-party experts on specific

topics. In 2023, Deloitte LLP delivered a board education

session on biodiversity and the upcoming Taskforce on

Nature-related Financial Disclosures (“TNFD”).

Key climate-related topics discussed by the Board

throughout 2023, included:

—Assessing progress on emission detection and

mitigation, including handheld fugitive surveys and

repair, pneumatic conversions, aerial LiDAR, and

compressor conversions;

—Reviewing output from the marginal abatement cost

curve ("MACC") and approving the Emissions Program

budget for 2023; and

—Ensuring proposed acquisitions are consistent with

emissions reduction targets and plans.

Using an internally developed acquisition emissions

screening tool, target assets are assessed for their methane

intensity in accordance with the Methane Intensity Protocol

developed by the Natural Gas Sustainability Initiative

(“NGSI"). This information is then used by the Board as one

metric to inform its acquisition decision-making. The NGSI

voluntary reporting protocol complements existing

regulatory reporting by providing a consistent, transparent

and comparable methodology for measuring and reporting

methane emissions throughout the natural gas supply chain.

Our Board Committees provide oversight of our climate-

related risks and opportunities although these

considerations are a primary focus of our Sustainability &

Safety Committee. The roles of the four Board Committees

are reflected in the climate-related governance framework

depicted below.

CLIMATE-RELATED GOVERNANCE FRAMEWORK - BOARD

MANAGEMENT’S ROLE IN ASSESSING & MANAGING

CLIMATE-RELATED RISKS & OPPORTUNITIES

Management remains abreast of climate-related issues

through (i) its knowledge of our industry, business

environment and ongoing operating activities, (ii) frequent

interactions with both internal and external stakeholders,

including senior leaders in the Group, state and national

regulators and investors, and (iii) engagement with

vendors, industry associations and benchmarking groups

where current trends and best practice operating standards

and emissions reductions solutions are shared.

Climate-related responsibilities are assigned to

management-level positions according to each individual’s

area of responsibility and contribution to our overall

corporate strategy.

Collectively, our executive team, including in part the CEO,

CFO, COO (formerly) and Executive Vice President-

Operations (presently), provide frequent climate-related

operational and financial updates to the Board at each

Board meeting and throughout the year via interim

communications. However, the CEO assumes ultimate

responsibility for delivery of the Group’s climate and energy

transition strategy, including management of climate-

related risks and opportunities.

Climate-related actions by management during the year

include, but are not limited to: ensuring annual budgets

include operating and expenses for climate initiatives;

considering the impacts of new or emerging climate-related

policy and regulatory development on the Group; aiding in

the design or advancement of emission reduction initiatives;

ensuring Board directives on climate are integrated into

appropriate compensation plans and monitoring progress

of the same; and considering the impact of potential

acquisitions on standalone and consolidated Group

emissions and decarbonization strategies.

40	Diversified Energy Company PLC Annual Report and Form 20-F2023

THE CULTURAL SHIFT UNDERPINS OUR TRANSITION TO

NET ZERO

Environmental management and the energy transition are

deeply embedded into our company’s culture and actions,

as climate impact is recognized as a key strategic

consideration across multiple business functions. For

example, we have trained and equipped 100% of our well

tenders to become leak detection and repair technicians.

Finding and repairing leaks has always been a priority for

Diversified and is truly just a daily routine for our employees

as we seek to positively impact our climate while delivering

a lower-carbon energy solution to market. Furthermore, at

an operational level, we have optimized well tender routes

to increase efficiency and reduce driving time, therefore

reducing emissions. We also use lightweight, fuel-efficient,

well-maintained vehicles to drive down fuel consumption.

In addition to the aforementioned responsibilities of various

teams with regard to climate oversight and action, the

figure below provides a broader view of certain individual

company departments whose actions incorporate

climate considerations.

CLIMATE CULTURE DRIVES DAILY ACTIONS

04_426107_1_gfx_focus on climate.jpg

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	41
STRATEGY<br><br>UNDERPINNED BY DE-METHANIZATION OF<br><br>OUR GAS PRODUCTION
---

The reduction of methane emissions is at the heart of our

corporate strategy and underpins our pragmatic approach

to the ongoing decarbonization of our operations.

While our de-methanization activities are focused on the

decarbonization of our existing assets, we are also keen to

explore opportunities that will help us utilize our asset

portfolio, as well as our skills and competencies, beyond our

current business model.

OUR NET ZERO PATHWAY: OUTPERFORMING

OUR TARGETS

In line with our pragmatic approach, we set out our

emissions reduction targets aiming to reduce Scope 1

methane intensity by 30% by 2026 and 50% by 2030,

reaching net zero from Scope 1 and 2 absolute GHG

emissions by 2040. We also set out our net zero pathway

showing how we plan to achieve our targets, beginning

with a near-term focus on methane emissions, as

depicted below.

We have been resolute in our focus on reducing emissions

from our operations. We are delighted that our significant

efforts to date, largely through the deployment of state-of-

the-art technologies for methane detection and reduction

and the conversion of natural gas-driven pneumatic

devices, have yielded outstanding results, with our 2030

methane intensity reduction target being achieved in 2023,

seven years ahead of schedule and directly aiding our

overall goal toward net zero in 2040.

Even so, we will continue to progress our decarbonization

strategy, focusing primarily on additional methane emission

reductions in the near-term as we seek to unpack the

impact on our reported emissions from new EPA

regulations where future real emission reductions could be

offset by potential increases stemming from both recent

and forthcoming changes in regulatory reporting

requirements. We are committed to tackling those changes

and delivering tangible results with continued financial

investment and diligent execution to achieve our 2040 net

zero GHG goal.

We discuss our deployment of decarbonization

technologies in the Climate-related Risks and Opportunities

tables on the following pages.

42	Diversified Energy Company PLC Annual Report and Form 20-F2023

CLIMATE-RELATED RISKS AND OPPORTUNITIES

In line with TCFD guidance, we consider climate-related

risks and opportunities that could have a material financial

impact on our business on a short-, medium- and long-term

basis. For this analysis, our considered timeframes are as

follows: short-term 2024 to 2026, medium-term 2027 to

2030, and long-term 2031 and beyond. The timeframes

align with our methane intensity reduction targets set for

2026 and 2030 while contributing to our net zero GHG

emissions goal in 2040.

The climate-related risks and opportunities presented

below were identified through workshops with executive

management, senior leaders, and third-party advisors as

well as through peer comparisons.

Climate-related risks have been grouped according to the

risk types suggested by the TCFD: Transition Risk

(including Market, Policy & Legal, Technology, and

Reputation) and Physical Risk (chronic and acute), while

climate-related opportunities are categorized as Resource

Efficiency, Energy Source, Products & Services,

and Markets.

The specific climate-related risks and opportunities

identified are set out in the following tables together with

the potential impacts they could have on our business, the

timeframes associated with each, and the progress being

made to mitigate or exploit them.

CLIMATE-RELATED RISKS

Risk	Potential Impact	Timeframe(a)			Risk Management Actions
		S	M	L
MARKET
Changing global<br><br>market sentiment<br><br>as consumers<br><br>transition away<br><br>from fossil fuels<br><br>will result in reduced<br><br>natural gas & oil<br><br>demand and impact<br><br>the price outlook	—Negative impact on<br><br>revenues and<br><br>portfolio value<br><br>—Reduced<br><br>opportunities<br><br>for acquiring<br><br>commercially<br><br>viable assets		•	•	—We conduct scenario analysis of portfolio impacts<br><br>under a range of commodity price and demand<br><br>outlooks to assess portfolio resiliency.<br><br>—Our portfolio is heavily weighted towards gas, which is<br><br>expected to remain more resilient than oil through the<br><br>energy transition, particularly in North America.<br><br>—Our low-cost production provides considerable<br><br>resilience to lower commodity price environments.<br><br>—Our robust hedging strategy provides financial<br><br>assurance and protection against commodity price<br><br>volatility in the short-, medium- and long-term.<br><br>—Our compliance with OGMP Gold Standard Pathway<br><br>will ensure we remain differentiated as a responsible<br><br>gas producer, helping us sustain our competitive<br><br>advantage through the decarbonization of our Scope 1<br><br>and 2 emissions.<br><br>—We are pursuing other differentiated gas initiatives like<br><br>TrustWell and other quantification-based efforts to<br><br>market our lower gas intensity.
Increased cost<br><br>of and more<br><br>challenging or<br><br>conditional access<br><br>to capital	—Investors/lenders<br><br>look to decrease<br><br>their portfolio<br><br>exposure to<br><br>hydrocarbon assets<br><br>—Capital available to<br><br>Diversified<br><br>may become<br><br>more difficult<br><br>to access, more<br><br>costly, or come<br><br>with additional<br><br>climate-specific<br><br>obligations	•	•	•	—We have committed to achieving Net Zero by 2040<br><br>from our Scope 1 and 2 emissions, aligning with<br><br>mainstream lenders and investors in Western capital<br><br>markets.<br><br>—Our existing levels of fixed-rate debt and amortizing<br><br>payments provide significant protection in the<br><br>short/medium term.<br><br>—We continue to pursue ESG-aligned asset-backed<br><br>securitization (“ABS”) financing structures, where our<br><br>achievement or out-performance of commitments to<br><br>ambitious ESG KPIs attached to these ABS financings<br><br>can improve borrowing rates and financing capacity.<br><br>—Our hedging strategy provides short- to medium-term<br><br>certainty and protection for cash flows available<br><br>for reinvestment.<br><br>—Our strategy of incremental M&A enables adaptation to<br><br>changing market or financing conditions.
Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	43
---	---	---	---	---
Risk	Potential Impact	Timeframe(a)			Risk Management Actions
---	---	---	---	---	---
		S	M	L
POLICY & LEGAL
Cost of carbon	—Implementation<br><br>of some form of<br><br>carbon cost or<br><br>regulation in states<br><br>where we operate<br><br>could increase<br><br>operating costs<br><br>and make our<br><br>natural gas less<br><br>competitive vs.<br><br>other forms<br><br>of energy<br><br>—Such policies could<br><br>also accelerate<br><br>pressure from<br><br>investors and<br><br>stakeholders to<br><br>reduce emissions<br><br>or improve<br><br>energy efficiency,<br><br>increasing our<br><br>decarbonization<br><br>costs		•	•	—Ongoing engagement in proactive, voluntary<br><br>measurement of our Scope 1 emissions to ensure we<br><br>fully understand potential portfolio liability.<br><br>—We continue to engage in efforts to reduce<br><br>emissions across our portfolio, such as leak detection<br><br>and repair, pneumatics replacements, and<br><br>compressor optimization.<br><br>—We engage in cost-efficient operations and deploy<br><br>SAM initiatives across our upstream and<br><br>midstream portfolio.<br><br>—We are engaging with third-party consultants to<br><br>more fully develop our internal price of carbon<br><br>metrics and strategy.<br><br>—We include the evaluation of acquisition targets’<br><br>carbon footprints in our M&A process and final<br><br>investment decisions.<br><br>—Our evolving internal MACC analysis aided by field<br><br>testing and/or small-scale pilot projects allows us to<br><br>optimize the prioritization of identified emissions<br><br>reduction projects.
Well retirement	—Acceleration of<br><br>existing state<br><br>well retirement<br><br>commitments<br><br>could significantly<br><br>increase annual<br><br>capital and<br><br>operating costs<br><br>—Underestimation<br><br>of well retirement<br><br>costs could<br><br>significantly<br><br>increase asset<br><br>retirement<br><br>obligation and<br><br>future cash outlay<br><br>for well retirement<br><br>activities		•	•	—We actively engage with regulators regarding well<br><br>retirement policies and activities.<br><br>—We are committed to retiring wells ahead of state<br><br>requirements (2023: 80 wells), including 201<br><br>Diversified-operated wells retired in 2023.<br><br>—Our low-cost retirement capacity enables us to increase<br><br>our own well-retirement targets, participate in state<br><br>orphan well programs and carry out asset retirement<br><br>for third parties.<br><br>—Our extensive experience of well retirement,<br><br>particularly in Appalachia, and our expanded<br><br>retirement capabilities puts us in the best position to<br><br>accurately forecast the future capital requirements for<br><br>these activities.<br><br>—Revenue streams from third-party asset retirements<br><br>help to offset the cost of retiring our own wells. In<br><br>addition, Diversified is exploring potential opportunities<br><br>in alternative energy uses for wellbores (e.g.<br><br>hydrogen production, carbon storage, mechanical<br><br>battery storage).	44	Diversified Energy Company PLC Annual Report and Form 20-F2023
---	---
Risk	Potential Impact	Timeframe(a)			Risk Management Actions
---	---	---	---	---	---
		S	M	L
Litigation	—Potential litigation<br><br>tied specifically<br><br>to Diversified’s<br><br>climate-related<br><br>reporting (e.g. for<br><br>misrepresentation)<br><br>or actions could<br><br>bring additional<br><br>legal and<br><br>reputational costs<br><br>—Potential litigation<br><br>around leaks or<br><br>other sources of<br><br>emissions (now<br><br>or historical)	•	•	•	—We have focused, near-term efforts to achieve Scope 1<br><br>methane intensity reductions with a goal of net zero<br><br>Scope 1 and 2 GHG emissions by 2040.<br><br>—We expect continued development, funding, and<br><br>execution of formal plans and projects will enable the<br><br>achievement of emissions targets.<br><br>—We continue to transparently report and communicate<br><br>climate and emission reduction initiatives, keeping<br><br>stakeholders abreast of such actions.<br><br>—We actively engage with federal and U.S. state<br><br>regulators, and consistently demonstrate our<br><br>commitment to meet or exceed their requirements.<br><br>—We maintain strong community support in our<br><br>operating areas.<br><br>—We are transitioning to an emissions intelligence<br><br>software, Iconic Air, to track, report, and manage<br><br>emissions, which will enable us to increase<br><br>transparency, improve the integrity of our emissions<br><br>measurements and therefore minimize potential<br><br>litigation risk around leaks.<br><br>—We work with independent consultants to verify our<br><br>GHG accounting.<br><br>—We engage an independent, third-party consultant to<br><br>provide moderate Level II assurance for Scope 1 & 2<br><br>GHG emissions.
Current &<br><br>emerging climate-<br><br>related regulation<br><br>and policy	—Increasing costs of<br><br>doing business as a<br><br>fossil fuel-focused<br><br>company;<br><br>regulatory fines for<br><br>emission levels;<br><br>regulatory<br><br>constraints on<br><br>hydrocarbon<br><br>commerce<br><br>—Mandates on and<br><br>regulation of<br><br>existing products<br><br>and services	•	•	•	—We actively monitor U.S. and international climate-<br><br>related regulations and frameworks and engage as<br><br>applicable, including: IFRS S1 & S2, Transition Plan<br><br>Taskforce, SEC Climate Disclosures and TNFD.<br><br>—We have multiple emissions reduction activities in<br><br>place aimed at reducing methane emissions and<br><br>achieving our 2040 net zero goal.<br><br>—We actively engage with industry associations to<br><br>ensure we are using best practices in operating<br><br>procedures and emissions reductions.<br><br>—Our experience from the many voluntary efforts<br><br>made to date to reduce our methane emissions<br><br>positions us to manage any impact arising from the<br><br>U.S. EPA OOOOb and OOOOc regulations and U.S.<br><br>Inflation Reduction Act’s Methane Emissions<br><br>Reduction Program.	Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	45
---	---	---	---	---
Risk	Potential Impact	Timeframe(a)			Risk Management Actions
---	---	---	---	---	---
		S	M	L
TECHNOLOGY
Cost of GHG<br><br>emissions detection<br><br>and reduction<br><br>technology	—Increased costs<br><br>of required<br><br>technology;<br><br>possible cost<br><br>upside if more<br><br>mitigation than<br><br>expected is<br><br>required		•	•	—Our emissions detection and reduction plans are<br><br>already well-advanced with short- and medium-term<br><br>costs factored into budgets.<br><br>—We continue to benefit from the successful use of aerial<br><br>and handheld leak detection equipment and from<br><br>continuous investment in our low-cost SAM program to<br><br>repair and eliminate fugitive emissions.<br><br>—We continue to invest in leading-edge emissions<br><br>reduction technologies and to monitor new technology<br><br>developments, including aerial LiDAR, compressor<br><br>conversions, handheld emissions detection, and<br><br>pneumatic conversions.<br><br>—We piloted two emerging emission detection and<br><br>quantification technologies in 2023. Both technologies<br><br>are expected to substantially reduce the cost of<br><br>emissions detection while providing emissions<br><br>quantification and a digital twin.<br><br>—To date, we’ve experienced lower-than-expected<br><br>costs of compressed air applications for pneumatic<br><br>controllers. Our internally developed solutions for<br><br>pneumatics and level controllers are well below<br><br>market prices.<br><br>—We continue to demonstrate innovative actions to<br><br>reduce emissions, including retrofitting/elimination of<br><br>existing emitting equipment (e.g. pneumatic devices<br><br>and compressors).<br><br>—Throughout 2023, we have continued to build and<br><br>maintain our emissions intelligence using Iconic Air<br><br>carbon accounting software to track, report and<br><br>manage emissions. Using Iconic Air will allow us to<br><br>streamline emissions accounting and reporting and<br><br>manage our emissions sources at the asset-level.
Substitution of<br><br>natural gas and oil<br><br>with lower-carbon<br><br>forms of energy	—Faster acceleration<br><br>and adoption/<br><br>substitution of<br><br>alternative energy/<br><br>lower carbon<br><br>solutions (i.e.,<br><br>electric vehicles,<br><br>more efficient<br><br>appliances) drives<br><br>lower demand for<br><br>natural gas and oil		•	•	—The scenario analysis shows that gas plays an<br><br>important role throughout the Energy Transition even<br><br>in the Net Zero scenario (accounting for 22% of global<br><br>energy demand in 2040).<br><br>—Our scenario analysis shows that even under low-<br><br>carbon scenarios our portfolio is relatively resilient. Due<br><br>to our low cost of production, we are able to maintain<br><br>profitable operations across our portfolio even under<br><br>low commodity price environments (see Portfolio<br><br>Resilience section).	46	Diversified Energy Company PLC Annual Report and Form 20-F2023
---	---
Risk	Potential Impact	Timeframe(a)			Risk Management Actions
---	---	---	---	---	---
		S	M	L
REPUTATIONAL
Overall perception<br><br>of fossil fuels/<br><br>energy sector	—Increased<br><br>stakeholder<br><br>pressure to<br><br>accelerate<br><br>emissions reduction<br><br>projects could<br><br>increase short-term<br><br>costs and challenge<br><br>profit margins<br><br>—Changes in<br><br>stakeholder/society<br><br>expectations of<br><br>Diversified’s role in<br><br>the energy<br><br>transition could<br><br>impact company<br><br>valuation or brand<br><br>—Increasing<br><br>challenge to attract<br><br>and/or retain talent	•	•	•	—We are committed to transparency in emissions and<br><br>climate risk reporting, and to our plan of achieving our<br><br>climate-related targets.<br><br>—We engage regularly with shareholders, regulators and<br><br>other key stakeholders to ensure understanding of our<br><br>climate strategy.<br><br>—We include climate metrics in short- and long-term<br><br>remuneration policies to incentivize ongoing<br><br>improvement in climate actions.<br><br>—We are continuing to explore longer-term opportunities<br><br>in new revenue-generating low-carbon energy projects,<br><br>for example through waste heat recovery.<br><br>—Broad leadership engagement through multiple<br><br>communication channels keeps our current employees<br><br>abreast of business strategy and emissions reduction<br><br>actions and results.<br><br>—Our community engagement initiatives and talent<br><br>acquisition programs, including scholarship and<br><br>internship programs, facilitate broader awareness of<br><br>the Company and its climate-related actions among<br><br>potential employee candidates.<br><br>—Our community tree planting programs, such as<br><br>Diversified’s 10,000 tree replanting effort with West<br><br>Virginia State University in 2023, support communities,<br><br>provide carbon sequestration, and increase the<br><br>company’s visibility and engagement with our<br><br>future talent.
PHYSICAL
Acute – Changing<br><br>weather patterns,<br><br>including increased<br><br>frequency and<br><br>severity of extreme<br><br>weather events<br><br>such as extreme<br><br>rainfall and<br><br>hurricanes	—Increased risk<br><br>of compromised<br><br>infrastructure<br><br>or forced<br><br>abandonment of<br><br>operations could<br><br>cause loss of<br><br>revenue and<br><br>decrease<br><br>portfolio value	•	•	•	—We have robust business continuity and crisis<br><br>management plans in place, which were tested during<br><br>the central Appalachia floods of 2022 and resulted in<br><br>minimal business disruption.<br><br>—We use 24-hour monitoring centers, enabling a more<br><br>rapid response to weather-related disruptions.
Chronic –<br><br>Persistent or<br><br>constantly<br><br>recurring weather<br><br>patterns, including<br><br>water stress and<br><br>heat stress	—Increasingly<br><br>challenging<br><br>and potentially<br><br>dangerous<br><br>environmental and<br><br>climate conditions<br><br>could increase<br><br>operating costs<br><br>and risks		•	•	—Our business model inherently requires minimal water<br><br>consumption in our operations.<br><br>—We maintain appropriate levels of insurance to<br><br>mitigate losses.<br><br>—The geographic spread of our asset portfolio mitigates<br><br>any large-scale disruption to production from individual<br><br>weather events e.g., flooding.<br><br>—Further details on our exposure to physical risks and<br><br>our qualitative assessment of our portfolio’s<br><br>vulnerability to identified hazards are described in a<br><br>separate section below.

(a)Timeframes are defined as S - short (2024 to 2026), M - medium (2027 to 2030), and L - long (2031 and beyond).

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	47

CLIMATE-RELATED OPPORTUNITIES

		Timeframe(a)
Opportunity	Potential Impact	S	M	L	Steps and Progress
RESOURCE EFFICIENCY
Emissions<br><br>monitoring and<br><br>replacement of<br><br>inefficient<br><br>equipment	—Early detection<br><br>of methane leaks<br><br>reduces the loss<br><br>of sales gas and<br><br>associated<br><br>revenues across<br><br>the portfolio	•	•	•	—To reduce our GHG footprint, we continue to invest in<br><br>remote leak detection, aerial surveillance, replacement<br><br>of pneumatic devices, and inefficient compressors.<br><br>—We actively track advances in emissions monitoring<br><br>technologies and plan to take advantage of any<br><br>suitable applications and technology cost reductions<br><br>that evolve.<br><br>—We continue to work on emissions intelligence<br><br>digitalization and automation plans, supporting the<br><br>connection of reported emissions data in the Iconic<br><br>Air software to our MACC tool, to enhance the<br><br>process of evaluating a broad scope of emissions<br><br>reduction projects.
Lowering vehicle-<br><br>derived carbon<br><br>emissions through<br><br>optimization and<br><br>more efficient<br><br>vehicles; waste<br><br>management<br><br>recycling	—Fuel and operating<br><br>cost savings by<br><br>using vehicles that<br><br>are more efficient<br><br>and have lower<br><br>carbon emissions		•	•	—We utilize lighter weight, more fuel-efficient vehicles in<br><br>our fleet replacement program, which could further<br><br>expand in the future to include the use of longer-range<br><br>electric vehicles.<br><br>—We are exploring new technologies to allow remote<br><br>operations at well sites thus reducing vehicle use and<br><br>associated emissions.<br><br>—We utilize optimized route mapping to create the<br><br>most efficient well tender routes thereby reducing<br><br>vehicle run time, maintenance, fuel consumption and<br><br>vehicle emissions.<br><br>—We work internally to identify opportunities to reduce<br><br>our carbon footprint within our office environment, for<br><br>example paper consumption and waste recycling.
ENERGY SOURCE
Increase use of<br><br>renewable energy<br><br>sources	—Replace natural gas<br><br>with renewable<br><br>energy sources to<br><br>support operational<br><br>power needs		•	•	—Diversified uses solar equipment and small wind<br><br>turbines to provide auxiliary power at certain smaller or<br><br>remote well sites and has been increasing the use of<br><br>solar equipment in its pneumatic conversion projects.<br><br>—38% of our sources for Scope 2 electrical usage in 2023<br><br>were zero carbon (including nuclear and renewables).<br><br>An additional 33% results from lower-carbon energy<br><br>sources (including natural gas) versus coal or<br><br>petroleum products.<br><br>—We are exploring new technologies to expand the use<br><br>of renewable and alternative energy in operations,<br><br>including waste heat recovery and solid oxide fuel cells.<br><br>Additionally, we are exploring the use of wellbores for<br><br>mechanical battery energy storage to aid in the energy<br><br>transition by providing off-peak energy storage.
48	Diversified Energy Company PLC Annual Report and Form 20-F2023
---	---
		Timeframe(a)
---	---	---	---	---	---
Opportunity	Potential Impact	S	M	L	Steps and Progress
PRODUCTS & SERVICES
Asset retirement<br><br>capabilities for third<br><br>parties	—Providing<br><br>third-party asset<br><br>retirement services<br><br>as an additional<br><br>revenue stream and<br><br>advancing states’<br><br>resolution of<br><br>orphan wells<br><br>—Support regional<br><br>well retirement<br><br>compliance<br><br>—Continue to build<br><br>internal asset<br><br>retirement<br><br>capabilities	•	•	•	—Our expanded well retirement capability supports<br><br>our regional leadership position in responsible<br><br>asset retirement.<br><br>—We see an opportunity to grow our retirement capacity<br><br>further via our subsidiary Next LVL Energy, positioning<br><br>Diversified to further support states’ efforts to eliminate<br><br>orphan wells.<br><br>—Potential for expanded services including the<br><br>generation of voluntary and regulated carbon credits<br><br>related to well retirement of orphan wells held by state<br><br>governments.<br><br>—Expanded plugging commitments increase return of<br><br>well pads to original, natural conditions thus supporting<br><br>natural reforestation and biodiversity initiatives in<br><br>those areas.
Fuel cells and<br><br>hydrogen<br><br>applications	—Explore potential<br><br>long-term revenue<br><br>opportunities in<br><br>blue hydrogen and/<br><br>or emissions<br><br>reductions using<br><br>fuel cells		•	•	—We continue to explore new opportunities in low-<br><br>carbon technologies.<br><br>—We are currently in the early stages of pursuing<br><br>partnerships to evaluate potential of using<br><br>existing midstream infrastructure for future<br><br>hydrogen applications.
Carbon capture<br><br>utilization and<br><br>storage (CCUS)	—Explore the<br><br>potential to provide<br><br>carbon storage<br><br>services to<br><br>neighboring<br><br>emitters<br><br>—Potential to offset<br><br>our Scope 1 & 2<br><br>emissions		•	•	—We are working with external partners to explore the<br><br>potential of using our gas storage capacity for CCUS.
Solar	—Opportunities<br><br>to lease land<br><br>surface rights to<br><br>third parties	•	•	•	—We are evaluating opportunities to expand surface<br><br>rights leases to third parties for their development of<br><br>solar power farms.
MARKETS
OGMP Gold<br><br>Standard<br><br>Recognition	—Recognition of our<br><br>commitment to<br><br>deliver responsibly<br><br>produced gas to<br><br>the market<br><br>—Enables further<br><br>differentiation of<br><br>our produced<br><br>natural gas versus<br><br>competitors	•	•	•	—Achieving Gold Standard Pathway in both 2022 and<br><br>2023 positions us to offer responsibly produced gas in<br><br>the marketplace to differentiate it from other natural<br><br>gas production.<br><br>—As a member of OGMP, Diversified is committed to<br><br>disclosing actual methane emissions data aligned with<br><br>the OGMP 2.0 framework, thus further increasing our<br><br>level of transparency for the market’s consideration<br><br>when seeking differentiated gas.

(a)Timeframes are defined as S - short (2024 to 2026), M - medium (2027 to 2030), and L - long (2031 and beyond).

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	49

EMBRACING ENERGY TRANSITION

TECHNOLOGIES MITIGATES RISKS AND

OPENS OPPORTUNITIES

MARGINAL ABATEMENT COST CURVE

(“MACC”) ANALYSIS

MACC is a tool that allows for the visualization of a portfolio

of projects that, when taken as a whole, provide

complementary choices for the most efficient reduction of

GHG emissions. Both the GHG emission reduction potential

and the associated abatement cost for each project are

identified within the MACC.

Anticipated emission reductions are estimated based on

source-specific emissions calculations or through direct

measurement. Total costs include direct costs for project

implementation and the value generated from the project,

including decreased product loss or reduced operating

costs. When estimated emission reduction costs and

benefits are combined in the MACC, emissions reduction

project ranking based on economic feasibility and potential

impact is realized.

We are utilizing our MACC analysis as a warehouse of

potential technologies identified through extensive research

and collaboration within the industry, where each

technology is at various stages of evaluation and

applicability. Of the first emphasis for us in the MACC was

natural gas-driven pneumatics, where we have now

identified multiple technologies and solutions that are

effective and promising for the elimination of methane

emissions from pneumatic controllers and pumps.

Before our use of the MACC, we began our pneumatic

controller emission reduction efforts two years ago,

targeting the highest emitting pads first. Now, with the

MACC’s capability to provide a conversion cost break point

of dollars per MT CO2e for a growing database of

alternative technologies, we can make more informed

decisions as to optimal locations and technologies for our

future conversion plans. Thus, going forward we currently

plan to employ customized solutions on a site-by-site basis

as informed by our MACC.

MACC CONSIDERATIONS IN EMISSIONS ABATEMENT (illustrative)

03_426107-1_stack_macc consideration.jpg

Diversified has achieved the OGMP 2.0 Gold Standard

Pathway for the second consecutive year. The OGMP 2.0 is

the only comprehensive measurement-based reporting

framework created to report methane emissions accurately

and transparently for the oil and gas industry. This award

recognizes our commitment to developing aggressive and

attainable multi-year plans to measure and reduce methane

emissions. Our team worked diligently to fulfil the

requirement throughout the year and continues to do so.

For our operated assets, Diversified has now achieved Level

4 on all but two of OGMP’s 10 categories, with only

methane slip and leak quantification data remaining to

address. As we look to close out these remaining two

categories for Level 4, we also continue to advance our

efforts to achieve Level 5 on all categories as per OGMP 2.0

Gold Standard expectations.

PHYSICAL RISK

We recognize that the physical risks of climate events can

impact our business. These risks have been incorporated

into our risk assessment through our Viability and Going

Concern assessment where we consider the impacts that

certain climate events may have on our production.

Physical climate risks are functions of hazard, exposure and

vulnerability and are therefore complex and frequently

multidimensional. They are related to tangible, physical

impacts of changes in climate and are considered either

acute or chronic. Acute physical risks are event-driven,

including weather events such as extreme rainfall, flooding,

droughts, or wildfires, whereas chronic risks refer to longer-

term shifts in climate patterns, such as rising temperatures

or rising sea levels.

HAZARD IDENTIFICATION

To identify key physical risks to our portfolio, we leveraged,

in part, data published by the American Communities

Project (“ACP”) which included physical risk projections

through 2040. The ACP climate risk analysis was

underpinned by data from Four Twenty Seven, an affiliate

of Moody’s specializing in physical climate risk. Pinkus, A.

(2021) “Mapping Climate Risks by County and Community”,

American Communities Project (accessed January 30,

2024). The 2040 data refers to IPCC’s RCP 8.5 scenario,

which assumes GHG emissions continue to grow

unmitigated, leading to a ‘hothouse world’ with an

estimated global average temperature rise of 4.3°C by

This scenario implies no concerted effort is taken by

society to cut GHG emissions. In contrast, the International

Energy Administration’s (“IEA’s”) most conservative

scenario, STEPS, assumes the implementation of existing

policies, leading to a 2.5°C rise in temperatures by 2100.

Therefore, the scenario used in our assessment of the

impact of physical climate risks on our portfolio is more

extreme than any of the three scenarios used to test the

resilience of our portfolio against the climate-related

transition risks.

50	Diversified Energy Company PLC Annual Report and Form 20-F2023

We focused on four key hazards that could impact Diversified’s portfolio: acute risks of extreme rainfall, hurricanes, chronic

risks of water stress, and heat stress. We carried out a qualitative assessment of our portfolio exposure to these hazards. The

impact of rising sea levels as addressed in the ACP report has not been analyzed, since we currently have no coastal or

offshore exposure.

IDENTIFIED HAZARDS IN THE STATES IN WHICH WE OPERATE*

*Includes high and extreme (red flag) risks only as per ACP data

Source: ACP, Diversified Energy

EXPOSURE ANALYSIS

Our upstream and midstream assets are considered

exposed if they are located in an area where a climate

hazard may occur. The degree of exposure is defined by the

intensity of that particular hazard, with the range of

exposure including no risk, low, medium, high, and extreme

risk (which corresponds to ACP’s ‘red flag’).

While our portfolio is located entirely U.S. onshore, our

exposure to suffering a significant financial loss from a

single extreme weather event is minimized due to the

dispersion of our production footprint over a large

geographical area covering nine states – Pennsylvania,

Ohio, West Virginia, Virginia, Kentucky, Tennessee,

Louisiana, Texas, and Oklahoma, with our headquarters

in Alabama.

We compared the locations of our current assets at the

county level to the same counties within the ACP analysis.

This enabled us to quickly assess the exposure of our

assets, and therefore production, to the projected 2040 risk

profile of those counties, as reflected below. We also

identified potential physical impacts associated with each

of the identified risks.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	51

OUR PROJECTED GEOGRAPHICAL EXPOSURE TO KEY PHYSICAL RISKS OF CLIMATE CHANGE IN 2040

| Acute | | --- || Extreme Rainfall | Hurricanes | | --- | --- |

Potential impacts:		Potential impacts:
—Disruptions of operations<br><br>due to flooding<br><br>—Infrastructure damage	—Supply chain disruption<br><br>—Increased operating costs<br><br>—Impact on revenue	—Infrastructure damage due to<br><br>extreme winds<br><br>—Operational disruption from<br><br>hurricanes	—Inland flooding<br><br>—Increased operating<br><br>costs<br><br>—Impact on revenue	Chronic
---		Water Stress	Heat Stress
---	---

Potential impacts:		Potential impacts:
—Reduced community<br><br>access to water<br><br>—Infrastructure cost of fresh<br><br>water supply	—Impact on supply chain<br><br>—Increased operating costs<br><br>—Impact on revenue	—Increased heat exposure is a health<br><br>and safety risk for people<br><br>—Decrease in work productivity<br><br>—Infrastructure failure due to excess<br><br>heat exceeding the design criteria<br><br>(gas leaks)	—Additional energy<br><br>needed for cooling<br><br>—Increased operating<br><br>costs<br><br>—Impact on revenue

Source: ACP, Diversified Energy

Using the ACP’s county-based hothouse world scenario,

and when considering each of these four risks, we believe

that our current portfolio is most exposed to extreme

rainfall. That is, we estimate that approximately 84% of our

projected production could be exposed to extreme rainfall

in 2040, as shown in the following table. It is important to

note that ACP’s analysis is at the county level, whereas our

assets may be located in a specific portion of the county

which may bear a different risk level than that of the overall

county. Thus, we believe our exposure will be mitigated by

the specific location of our wells within the counties that

are exposed to extreme rainfall risk, for example. Further,

we estimate that less than 3% of our existing production is

located in a designated flood plain.

52	Diversified Energy Company PLC Annual Report and Form 20-F2023

OUR PRODUCTION EXPOSURE TO KEY PHYSICAL RISKS

Physical Risk		% of Diversified’s<br><br>Projected 2040<br><br>Production in<br><br>High or Extreme<br><br>Risk Areas
Acute Risk	Extreme Rainfall	84%
	Hurricanes	4%
Chronic Risk	Water Stress	22%
	Heat Stress	41%

VULNERABILITY ASSESSMENT

Our qualitative assessment of vulnerability addresses the

sensitivity of our operations to the respective hazard,

including actions taken to reduce or adapt to the hazard.

Acute Physical Risks

Extreme rainfall and associated risk of flooding represent

the highest risk to our assets in the Appalachian Basin in

2040, especially in Kentucky, Ohio, and West Virginia,

where our exposure to this risk is characterized as extreme.

Indeed, in July 2022, several central Appalachia states

within our footprint, including primarily Kentucky but also

Virginia and West Virginia to a lesser extent, experienced

devastating floods resulting in loss of life and extensive

damage to housing and public infrastructure within the

states. While the flooding also temporarily impacted our

operations, including compressor facilities, communications,

and pipelines, we were able to efficiently restore the

affected facilities to operations within approximately 10

days. This flooding event did not require the full

implementation of our formal Crisis Management and

Business Continuity plans, yet our teams were able to

professionally respond as a result of our preparation for

such events.

Hurricanes represent a moderate risk to our portfolio, with

only limited increased exposure in Texas and Louisiana,

where this risk is characterized as medium-to-high and is

largely a function of the states’ location on the U.S. Gulf

Coast where Atlantic Basin hurricanes have historically, in

part, impacted the coastline. In the last three years, since

we acquired our first Central Region assets in 2021, the

Texas and Louisiana coastlines have directly experienced

two out of a total of 22 recorded hurricanes in the Atlantic

Basin with no impact on our inland operations.

From a mitigation perspective, we aim for prevention rather

than response when it comes to physical impacts to our

business from any emergency, including those which may

be climate-related. This prevention starts with training our

employees to respond to potential emergencies such as

natural disasters, where all emergency response-related

processes exceed the needs of situations that may arise.

We are also prepared to be effective and expeditious in our

response to any emergency as a function of our separate,

formal Crisis Management and Business Continuity plans

which are reviewed at least twice annually by senior

leadership and which help to ensure the resilience of our

critical business functions and the safety of our employees

and other stakeholders in the case of significant business

disruption. The resilience of our systems is supported in

large part by our intentional, 100% cloud-based information

systems strategy which eliminates the physical risk

exposure of this aspect of our business.

Our Central Region acquisitions in 2021 and 2022 also

brought three district Integrated Operations Centers

(“IOCs”) into our portfolio, two in our upstream operations

and one in our midstream operations. These IOCs

complement our existing gas control center in West

Virginia which monitors the majority of our midstream

Appalachia assets. These 24-hour monitoring centers

facilitate streamlining the collection, standardization and

dissemination of timely, decision-useful data for both

normal operations and atypical events such as those

created by physical climate risks. The central management

of data through these remote monitoring centers leverages

our supervisory control and data acquisition (SCADA)

system and therefore affords a more rapid response to

weather-related disruptions.

Further, we consistently maintain appropriate levels of

hazard risk insurance coverage that mitigate potential

material financial losses from extreme weather events, such

as extreme rainfall, tornadoes, hurricanes, etc.

Chronic Physical Risks

Water stress is the most significant chronic physical risk

associated with our portfolio in 2040, particularly for our

assets in Texas and Oklahoma, where this risk is

categorized as high. Nevertheless, our business model is

focused on operating existing assets, rather than the

extensive drilling of new wells which requires significant

amounts of water for completion of the wells. To date, we

have not experienced an instance of water use limitations

or restrictions when fresh water has been needed for our

typical field and well operations or asset retirement

activities. Therefore, we do not anticipate any significant

disruptions to our operations from this risk categorization.

We do recognize, however, that the increased risk of

drought-like conditions can impact local communities and

ecosystems, lead to increased cost of freshwater supply

where we do intake water, and potentially affect our supply

chain. We expect to adapt to these conditions, especially

since we already operate in these areas which are subject

to strict environmental regulations. Our approach to water

management is to minimize freshwater use where possible,

particularly in potential water-scarce areas within our

operating footprint, as described in our Climate Policy and

Environmental, Health & Safety Policy.

In our Sustainability Report, we assess our current exposure

to water stress, as defined by the World Resources

Institute’s Aqueduct Water Risk Atlas. Even though our

current exposure to water stress risk primarily qualifies as

Low Overall Water Risk, we continue to apply a responsible

approach to water use, aimed at limiting freshwater use,

managing our produced water, and recycling and reusing

produced water as and where applicable.

Heat stress is likely to have a moderate-to-high impact on

our portfolio, with the highest exposure in Oklahoma,

Kentucky, West Virginia and Virginia. We consider heat

stress from two perspectives: (1) personnel and (2)

infrastructure. While we recognize that heat stress is a

health and safety risk for personnel and could lead to a

decrease in work productivity, we have programs and

processes currently in place to address this concern daily,

given the number of field personnel working outdoors and

the nature and volume of work that must occur outside as a

result of our asset portfolio. We also hold adequate levels

of insurance coverage for heat stress-related incidents that

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	53

may require medical attention. As the risk of heat stress

increases, we are confident that our current health and

safety procedures can be successfully adapted, as

applicable, to mitigate the impact of this chronic risk on

our operations.

Our Smarter Asset Management operations program helps

mitigate the potential impacts of heat stress on our

infrastructure. The program consists of ongoing, consistent

asset inspection and maintenance and remote monitoring.

This information allows for a rapid response to any

infrastructure or equipment failures that may occur due to

excessive heat.

PORTFOLIO RESILIENCE

Following TCFD guidance and to ensure comprehensive

business planning, we evaluate the resilience of our

portfolio under multiple future climate scenarios. Each

scenario includes assumptions about how the energy

transition may evolve, with differing commodity price

and demand outcomes, providing a range of outlooks

against which our portfolio is tested to evaluate and

determine resilience.

SCENARIO ANALYSIS

The three scenarios we selected to test our portfolio

climate resilience are:

(a)IEA’s Stated Policies Scenario (“STEPS”)

(b)IEA’s Announced Pledges Scenario (“APS”)

(c)Wood Mackenzie’s Accelerated Energy Transition 1.5-

degree pathway (“AET-1.5”), a global net zero by

2050 scenario

It should be noted that there are some differences in the

categorization of specific fuels in the Wood Mackenzie

versus the IEA’s scenarios. For example, in the Wood

Mackenzie AET-1.5 scenario, liquid biofuels are included

within oil whereas they are included with bioenergy in the

IEA scenarios.

TOTAL PRIMARY ENERGY SUPPLY AND CO2 EMISSIONS FOR EACH SCENARIO

AET -1.5		IEA APS(a)(c)		IEA STEPS(b)(c)
Total Primary Energy<br><br>Supply (1018 J)	CO2 Emissions<br><br>(GT)	Total Primary Energy<br><br>Supply (1018 J)	CO2 Emissions<br><br>(GT)	Total Primary Energy<br><br>Supply (1018 J)	CO2 Emissions<br><br>(GT)

03_426107-1_legend_energy supply.jpg

(a)Based on IEA data from the Announced Pledges Scenario of the IEA (2023) World Energy Outlook, www.iea.org/weo<br><br>(b)Based on IEA data from the Stated Policies Scenario of the IEA (2023) World Energy Outlook, www.iea.org/<br><br>(c)Further detail on the IEA’s pricing methodology for the APS and STEPS scenarios can be found in the 2023 World Energy Outlook.

AET -1.5

This scenario represents the most aggressive energy

transition scenario we considered, consistent with limiting

global warming to 1.5°C, in line with the most ambitious

goals of the Paris Agreement. In AET-1.5, global energy

supply peaks in 2024 due to more aggressive policy action

and accelerated global decarbonization efforts, which result

in an increase in electrification and adoption of new-energy

technologies in place of hydrocarbons. Under this scenario,

oil demand peaks in 2024 and then declines, from ~100

million barrels of oil per day (“MMBO/d”) to ~30 MMBO/d in

As a result, near-term oil prices fall rapidly, from

current levels to ~$52 per barrel (“/bbl”) in 2030 and then

continue to decline more gradually reaching ~$30/bbl by

Under this scenario the global economy achieves net

zero carbon emissions by 2050, aligned with the IEA’s own

net zero scenario.

The forecasts for natural gas demand and prices under this

scenario are more nuanced due to the assumed role of

natural gas as a global transition fuel and the relatively

rapid decline of oil prices in the future. This position is

particularly apparent in the U.S. market where the resilience

of gas demand is supported through the development of

carbon capture and storage, which supports low carbon

power generation and heating for industrial process as well

as blue hydrogen and ammonia.

AET-1.5 sees global natural gas demand peaking in 2027

and then falling below 2023 levels by 2030, with a

continued decline forecast thereafter. U.S. natural gas

demand remains particularly robust out to 2040 with near-

term policy (i.e. Inflation Reduction Act) support for the

development of carbon capture and storage along with

sustained LNG exports. While overall global natural gas

demand declines from 2027, the rapid decline in global oil

prices has a dramatic impact on the availability of relatively

54	Diversified Energy Company PLC Annual Report and Form 20-F2023

low-cost associated U.S. gas. Significant levels of

production from the liquids-rich plays in the U.S. (such as

the Permian) become sub-commercial thus cutting off

some of the country’s lowest-cost supplies. In order to

balance the market, higher cost non-associated gas is

required thus driving up the marginal cost of supply.

While U.S. natural gas demand does decline, this decline is

more than offset by the decline in supply from the liquids-

rich basins and thus the U.S. Henry Hub natural gas price is,

perhaps counter intuitively, forecast to increase

significantly in the period to 2032, from $2.61/million Btu

(“MMBtu”) in 2023 to $4.05/MMBtu by 2032. Thereafter,

prices continue to increase through the 2030s and 2040s,

albeit at a slower pace, reaching $4.80/MMBtu by 2050.

IEA APS

This scenario assumes that governments will meet, in full

and on time, the climate commitments they have made,

including their Nationally Determined Contributions and

longer-term net zero emissions targets. This scenario is not

designed to achieve a particular outcome and does not

result in a net-zero world by 2050.

Under APS, there is a pronounced decline in oil demand

driven by the implementation of policies aimed at reducing

oil consumption. Demand gradually declines from ~102

MMBO/d

in 2023 to ~93 MMBO/d in 2030, before an accelerated

decline to 55 MMBO/d by 2050. In conjunction, oil prices

see a similar decline, stabilizing at around $74/bbl in 2030

before declining to $60/bbl by 2050. Global natural gas

demand declines steadily, dropping about 40% from its

2021 peak by 2050. U.S. natural gas prices increase from

$2.61/MMBtu in 2023, reaching their plateau around $3.00/

MMBtu over the 2030s before declining to below $2.70/

MMBtu from 2040 onwards.

IEA STEPS

This scenario is the least ambitious energy transition

scenario used for our portfolio analysis and is designed to

provide a sense of the prevailing direction of energy system

progression, based on a detailed review of the current

policy landscape.

In this scenario, oil demand will grow in the near-term to

2030 to reach 102 MMBO/d. Demand then declines out to

2050, reaching 97 MMBO/d. Global natural gas supply

mirrors the growth pattern of oil, rising steadily to a gentle

peak level in 2030 that plateaus through 2050. U.S. natural

gas prices decline from $4.96/MMBtu in 2023 to $4.00/

MMBtu in 2030. From 2030, price begins to gradually

increase over the next two decade reaching $4.30/MMBtu

by 2050.

DEC’s BASE CASE PRICE SCENARIO

Diversified’s base case price forecasts, which are used for the calculations of net asset value and free cash flow, are based on

the NYMEX forward curves from 2024-2032 for Henry Hub (“HH”) and 2024-2029 for West Texas Intermediate (“WTI”) as of

December 31, 2023. The prices are kept flat in real terms thereafter.

Oil Comparison 2023 - WTI

U.S. Gas Price Comparison 2023

*Diversified Energy’s Henry Hub price is calculated based on 1030 BTU/standard cubic foot

PORTFOLIO IMPACT

We use the published price forecasts for oil and U.S. natural

gas from each scenario to assess the potential impact on

the value of our assets compared to our base case. It is

important to note, however, that this analysis considers

only our current assets. No account is taken of the impact

that future acquisitions or divestitures may have on our

future business value and cashflows.

The following table shows the impact of the three climate

scenarios relative to the base case for our current portfolio,

in terms of net asset value (“NAV”) change in percent

versus base case.

NAV CHANGE % vs. BASE CASE

Scenario	Portfolio Value Impact (NPV10)
STEPS	18% <br>
APS	-24% <br>
AET -1.5	7% <br>

Our NAV change is positive under the Wood Mackenzie

AET-1.5 and IEA STEPS scenarios, driven by two

main factors.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	55

Firstly, both scenarios forecast robust U.S. gas prices out to

2050, at $4.30/MMBtu and $4.80/MMBtu for 2050 under

STEPS and AET-1.5, respectively. The results illustrate our

conservative approach to financial planning, with our Henry

Hub price forecast aligned with the AET 1.5 scenario out to

2030 and staying flat at around $3.50/MMBtu post-2030.

The higher positive NAV change under the STEPS scenario

can be attributed to much higher Henry Hub prices out to

2030 than in our Base Case, which when coupled with

Diversified's front-loaded production outlook, significantly

increases the value of assets. Production volumes between

2024 and 2035 account for over 60% of the total

production between from 2024 to 2048. During this

timeframe, natural gas prices are higher in the STEPS

scenario, averaging ~$4.30/MMBtu versus an average of

~$3.70/MMBtu under AET- 1.5.

Secondly, the strong price outlook is bolstered by our low

cost of production. As a result, we are able to maintain

profitable operations across our portfolio through to 2050.

Our analysis indicates that even in the most carbon

constrained scenario (Wood Mackenzie AET-1.5), our

production would remain resilient and profitable in the

short-, medium- and long-term. This conclusion is

supported by the analysis of related free cashflows,

depicted below, where even under the most aggressive

pricing outlook in AET-1.5, our free cashflow

remains positive.

Unless there are significant changes in the regulatory

environment in the near future, we do not expect to see a

significant financial impact of climate-related risks on our

near-term cash flows. Post-2030, our conservative

commodity price assumptions, used for Diversified’s

financial planning and acquisition and divestiture screening,

position us well to cope with the potential introduction of

carbon taxes in the U.S. or falling commodity prices.

CUMULATIVE UNLEVERED FREE CASH FLOWS UNDER

EACH SCENARIO vs BASE CASE

CARBON COSTS AND REDUCTIONS

In addition to the impacts of the three climate scenarios on

commodity prices, the scenarios also incorporate carbon

price outlooks required to achieve the highlighted primary

energy outcomes. While the IEA acknowledges that these

estimates should be interpreted with caution, the CO2

prices provide some context for the level of price that is

required to promote fuel switching and associated

investment decisions. To assess the impact that carbon

pricing may have on our business, we have utilized the

carbon price forecast for the U.S. for the IEA scenarios and

for developed economies in the Wood Mackenzie AET-1.5

scenario. We have evaluated the implications based of

these carbon prices on our net zero goal (Scope 1 and 2).

Under the APS scenario, carbon prices in the U.S. are

forecast to be $135/MT in 2030 and rise to $175/MT by

STEPS does not incorporate a carbon cost in the U.S.

(at a country level) across the forecast period. The AET-1.5

scenario incorporates carbon prices of $96/MT as soon as

2026, thereafter increasing to $136/MT by 2030 and $173/

MT by 2040.

METHANE INTENSITY TARGETS

(MT CO2e/MMcfe)

	Carbon Prices (/MT)
Scenario	2026	2040
IEA STEPS	N/A	N/A
IEA APS	N/A	175
WM AET 1.5	96	173

All values are in US Dollars.

In 2021 we announced our ambitions for near- and long-

term emissions reductions relative to our revised 2020

baseline, with short- and medium-term targets to reduce

Scope 1 methane emissions intensity by 30% by 2026 and

50% by 2030. Based on our revised IPCC 2020 baseline

methane intensity of 1.6 MT CO2e/MMcfe, our targets are

therefore 1.1 MT CO2e/MMcfe by 2026 and 0.8 MT CO2e/

MMcfe by 2030. In addition, we have a long-term goal to

achieve net zero Scope 1 and 2 GHG emissions by 2040.

Our revised IPCC 2020 baseline for CO2 emissions intensity

across both Scopes for 2020 was 2.1 MT CO2/MMcfe.

Using the carbon price assumptions used in each of the

climate scenarios, the potential financial impact associated

with our methane emissions intensity targets in 2030 would

be $0.11/Mcfe under APS and $0.11/Mcfe under AET-1.5. The

carbon cost per Mcfe is calculated using the carbon price

from each scenario and multiplying this by the methane

intensity target for each of the target years, i.e. 2026, 2030

and 2040. As we have already surpassed our 2030

methane reduction target in 2023, the potential financial

impact of our methane emissions will likely be lower than

the calculated value above as we continue to focus our

efforts on de-methanization of our operations. There would

be no cost to our business under STEPS as this scenario

does not incorporate a U.S. carbon price. These figures do

not account for any additional costs from emissions of CO₂.

56	Diversified Energy Company PLC Annual Report and Form 20-F2023

Although we have not yet set specific targets for reducing

the intensity of our CO₂ emissions, if for the purposes of

this analysis we assume that we can reduce these at the

same rate as the intensity of our methane emissions, we

would expect our total Scope 1 and 2 emissions intensity in

2030 to be 1.05 MT CO2e/MMcfe, implying a total potential

carbon cost in 2030 (covering CO₂ and methane) of just

over $0.14/Mcfe in both APS and AET-1.5 scenarios.

Alternatively, if we take a less optimistic view and assume

that our CO₂ emissions remain at 2020 levels until 2030,

then the total intensity of our emissions would be 1.3 MT

CO2e/MMcfe, implying a total carbon cost in 2030 of close

to $0.18/Mcfe.

We aim to reduce our absolute Scope 1 and 2 GHG

emissions in line to achieve net zero in line with our 2040

goal. We would expect this to reduce the overall carbon

cost to our business from these emissions even in the face

of rising carbon prices. However, we recognize that our

2040 net zero goal assumes that there will still be residual

emissions from our operations which will need to be offset

elsewhere and that we may therefore still incur a carbon

cost associated with those residual emissions. We plan to

build these considerations into our financial models as the

pathway for our emissions after 2030 and for carbon

pricing becomes clearer in the coming years.

RISK MANAGEMENT<br><br>IDENTIFYING, ASSESSING AND MANAGING<br><br>CLIMATE-RELATED RISKS AND<br><br>OPPORTUNITIES

We recognize that the transition to a lower-carbon future,

inclusive of both physical and transition risks, could have

significant implications for our corporate strategy and

could negatively impact our financial results due to lower

demand and lower prices for natural gas and oil. The size

and scope of market-related climate risks are assessed and

quantified through scenario analysis as detailed in the

Strategy section of this TCFD Report. Equally, we recognize

that physical risks, such as extreme rainfall, water stress,

and heat stress, related to climate variability, could impact

our operations. The Strategy section also shows details of

our qualitative analysis of the impact of specific acute and

chronic physical risks on our portfolio, including mitigation

and adaptation actions.

We also actively monitor our performance against our

peers and engage with industry organizations such as the

Natural Gas Sustainability Initiative (“NGSI”) and OGMP to

ensure that our approach to climate risk, particularly the

decarbonization of our operations, follows best practice, as

described elsewhere in this TCFD Report.

This section of the TCFD Report focuses on our risk

management processes, including how we identify, assess,

and manage climate-related risks.

Effective risk management and control is a key component

to the successful execution of our business strategy and

objectives. Under the oversight of the Board’s Audit & Risk

Committee, our Senior Leadership Team developed risk

management review processes which include the oversight

and monitoring of our risk control and mitigation efforts.

These risk management processes were developed to

minimize risks across our operations, support the

achievement of our strategic objectives, and create

sustainable value for our stakeholders.

As part of our ERM program, we seek to assess all potential

risks, including climate-related, affecting stakeholders and

the natural environment and to counteract and mitigate

such risks as effectively and expeditiously as possible. Our

company-wide risk management processes ensure risks are

appropriately identified, assessed, and managed.

RISK IDENTIFICATION

Within the program’s risk identification phase, we capture

potential and emerging risks that could arise as a result of a

change in circumstances or new developments impacting

our company. To identify climate-related risks, we rely on

discussions with business unit leaders across the

organization, the experience and expertise of our Board

members, third-party experts, and our knowledge of

current and emerging industry- or company-specific risks.

Through consistent, robust stakeholder engagement and

our periodic corporate Materiality Assessment with

stakeholders, we also have the opportunity to identify

issues with the greatest impact, whether through risks or

opportunities, on our business. In 2023, climate and climate

management was identified by our stakeholders as a top 25

issue for the Group.

Climate-related risks are classified in alignment with the

TCFD’s description of physical and transition risks, as

described in the Strategy section above.

RISK ASSESSMENT

We assess climate-related risks to our business by utilizing

a scorecard approach, alongside other risk categories

considering their (i) likelihood, (ii) potential impact, and (iii)

speed of impact. For each Principal Risk, we also develop a

list of mitigating activities and other opportunities that may

offset or minimize the risk. In our most recent risk

assessment, we identified Climate as a Principal Risk, and

further, as a Strategic Risk within Diversified’s risk universe

when considering the potential it has to also influence

several other Principal Risks including Corporate Strategy

and Acquisition Risk, Regulatory and Political Risk, and

Commodity Price Volatility Risk.

RISK MANAGEMENT

While we consider risk management the responsibility of all

employees and have empowered them to enhance our

processes and procedures as appropriate to mitigate risks,

a designated Risk Owner is primarily responsible for

implementing the identified mitigating controls and action

plans in order to remove or minimize the likelihood and

impact of the risk before it occurs. As more fully described

below, the Risk Owner also provides updates to Executive

and senior management and the Board, as applicable, on

mitigation efforts of the risk.

Integration of Risk Management Processes into the

Organization’s Overall Risk Management

As described in part in the Governance section of this TCFD

Report, the ownership structure for Climate Risk is shown

below and begins with the Board’s responsibility to ensure

that Climate Risk is ultimately addressed and mitigated

through the Group’s corporate strategy and business

model. Assuming oversight responsibility of Climate Risk on

behalf of the Board, the Sustainability & Safety Committee

monitors company performance on operational climate

mitigation activities and energy transition adaptation plans

by actively engaging with senior management on these

topics.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	57

At the risk level, each Principal Risk is assigned to a Risk

Owner, a member of senior management who identifies and

develops mitigating controls and future opportunities for

mitigation as part of the risk scorecard process. Throughout

the year, under the oversight of an Executive Risk Owner,

the Risk Owner is responsible for actively monitoring and

managing the risk and likewise periodically updating the

risk scorecard.

As part of our ERM program, the role of Risk Owner for

Climate Risk is assigned to the Senior Vice President-

Sustainability. This Risk Owner, other senior management

team members, the Executive Risk Owner, and the CEO

regularly engage in risk discussions across all areas of our

operations, ensuring climate-related risks are integrated

into the Group’s overall and ongoing risk management

considerations, processes and actions. This healthy dialogue

regarding risk creates a culture that highly regards risk

mitigation as a way to preserve and create value for our

stakeholders. As a standing invited guest to the

Sustainability & Safety Committee meetings of the Board,

the Climate Risk Owner also regularly shares the Group’s

actions and mitigating activities regarding Climate Risk.

As a company, we also monitor emerging energy transition

trends and shifting conditions in the energy industry –

ranging from new climate-related regulatory requirements

to global climate impacts – so we are prepared to respond

accordingly. Such a response may include policy or

procedural changes or additional resources or training to

mitigate the emerging risks.

CLIMATE RISK OWNERSHIP STRUCTURE

Additional details of our ERM framework and program are

set out within this Annual Report .

Looking ahead, in 2024, the broader ERM program that

includes Climate Risk will be facilitated by our Senior Vice

President of Accounting who, under the ongoing oversight

of the Audit & Risk Committee, will:

—Engage Executive Management for a full review and

consensus of the Tier I and Tier II risks within our

risk universe;

—Assess the impact of the risks to corporate strategy and

develop relevant KPIs;

—Ensure Risk Owners develop, monitor, manage, and

report risk mitigation activities and opportunities to

Executive Management; and

—Present a full summary of the risks, KPIs, mitigating

actions, and opportunities to the Board.

METRICS & TARGETS<br><br>Beating Our Emissions Targets on Our<br><br>Path Towards Net Zero

FOCUS ON SCOPE 1 & 2 EMISSIONS

We have been resolute in our focus on reducing GHG

emissions from our operations throughout 2023 with a

particular focus on reducing methane intensity,

underpinned by our clearly defined targets, relative to the

2020 baseline:

—30% reduction in Scope 1 methane intensity by 2026;

—50% reduction in Scope 1 methane intensity by 2030; and

—Net Zero from Scope 1 and 2 GHG emissions by 2040.

Methane emissions have a magnified impact on climate

change due to their high global warming potential

compared to carbon dioxide, hence our focus on reducing

the methane intensity of our operations. The significant

progress we are making in achieving our targets is reflected

in the reported emissions table below, reflective of our

58	Diversified Energy Company PLC Annual Report and Form 20-F2023

achievement in 2023 of a methane intensity of 0.8 MT

CO2e/MMcfe, a 50% reduction from our 2020 baseline and

the accomplishment of our 2030 target seven years ahead

of schedule. This is also reflected in year-over-year change

in the portion of Scope 1 methane emission as to total

Scope 1 emissions, or 27% at year-end 2023 versus 38% at

year-end 2022.

Nonetheless, our primary focus remains on continuing near-

term efforts to further reduce the methane intensity of our

operations. This desire is driven by our longer-term goal to

achieve net zero emissions though we move forward

cautiously, within a regulatory environment that is

continuing to evolve and has the potential to increase our

reported emissions with the addition of new requirements

and new source categories not previously reported. As

such, we intend to evaluate those regulations as we

consider new interim targets.

As previously shared, we plan to increase in the medium-

term our efforts to reduce the combustion-derived CO2 in

our operations through efficiency improvements, potential

electrification, and the potential broader use of

renewable energy.

After focusing on true reductions and/or eliminations of

GHG emissions, whether methane or CO2, we will then seek

to address residual operating emissions through the use of

credible offsets and the generation of voluntary and

regulated carbon credits. We believe that this approach

sets us on course for the achievement of our longer-term

goal of net zero Scope 1 and 2 GHG emissions by 2040.

ACTIVITY LEVELS FOR THE KEY STEPS TOWARDS NET ZERO

REPORTING GHG EMISSIONS

To monitor our progress towards achieving our GHG emissions reduction targets and ultimate net zero goal, we collect and

evaluate a comprehensive set of metrics that are material to our performance. These metrics, which include our absolute

Scope 1 and 2 GHG emissions broken down by type and source, are also included in the GHG Emissions table below. Scope 1

and 2 GHG emissions data were assured by ISOS Group Inc. (“ISOS”). ISOS provided a moderate Level II assurance in

accordance with the AccountAbility 1000 Assurance Standard.

GHG Emissions(a)	Unit	2023	2022	2021
Scope 1 Emissions:	thousand MT CO2e	1,561	1,820	1,631
Carbon Dioxide	thousand MT CO2	1,140	1,130	841
Methane(b)	thousand MT CO2e	420	686	790
Nitrous Oxide	thousand MT CO2e	1	4	1
% Methane	%	27	38	48
Scope 1 Methane Intensity	MT CO2e/MMcfe	0.8	1.2	1.5
Scope 1 Methane Intensity - NGSI(c)	%	0.11	0.21	0.28
Scope 1 Emissions Attributable to:(b)(d)
Flared Hydrocarbons	thousand MT CO2e	—	0	0
Other Combustion	thousand MT CO2e	1,178	1,173	870
Process Emissions	thousand MT CO2e	92	67	65
Other Vented Emissions	thousand MT CO2e	63	182	295
Fugitive Emissions	thousand MT CO2e	228	399	402
Scope 2 Emissions - Total Company(b)	thousand MT CO2e	61	59	3
Energy consumption	million kWh	134	128	7
Total Scope 1 and Scope 2(b)	thousand MT CO2e	1,622	1,879	1,634
Scope 1 and Scope 2 GHG Emissions<br><br>Intensity(b)	MT CO2e/MMcfe	3.1	3.4	3.1
Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	59
---	---	---	---	---
Air Quality(a)(e)	Unit	2023	2022	2021
---	---	---	---	---
Nitrogen Oxide (NOx, excluding N2O)	metric tons	21,520	21,546	16,126
Carbon Monoxide (CO)	metric tons	18,448	18,530	13,842
Sulfur Oxide (SOx)	metric tons	61	108	81
Volatile Organic Compounds (VOC)	metric tons	3,108	4,421	6,632
Particulate Matter (PM Total)	metric tons	137	140	105

Totals may not sum due to rounding.

(a)Emissions are reported under a modified Intergovernmental Panel on Climate Change (“IPCC”) report format for EU investors.

(b)Based on a 100-year global warming potential of 28 for methane, in line with IPCC’s Fifth Assessment Report.

(c)Using the Natural Gas Sustainability Initiative protocol, and to support direct comparability among the industry’s producers, represents

methane intensity using methane emissions from production assets only (therefore, excluding gathering & boosting facilities) divided by

gross natural gas production.

(d)Reflects Sustainability Accounting Standards Board categories for reporting Scope 1 GHG emissions (EM-EP-110a.2) in line with the Oil & Gas

– Exploration & Production Sustainability Accounting Standard (October 2018).

(e)2022 and 2021 were recast from previous disclosures to mirror like computations in 2023, inclusive of updated calculation assumptions and

new approved reporting protocols, thus improving year-over-year comparability.

Disclaimer: GHG emissions were calculated per IPCC reporting guidance, which permits best engineering estimates for certain emissions

categories, and which may vary from the prescriptive measures applied under U.S. EPA reporting standards. The source data used in these

calculations were accurate and complete, to the best of our knowledge, at the time they were gathered and compiled. If new data or corrections

to existing data are discovered, the Group may update emissions calculations as permitted and in accordance with industry standards and

expectations. Such updates will be included in future reporting and posted to our website at www.div.energy where such posts may take place

without notice.

We have continued to focus our efforts on the reduction of

methane emissions from our operations with significant

success reflected in achieving our 2030 target seven years

ahead of schedule. As the bulk of our methane emissions

are largely a function of fugitive emissions and natural gas-

driven pneumatics, we have continued to address these

areas. Throughout 2023, we built upon previous

achievements and continued to pursue aggressive leak

detection and repair initiatives, as discussed in our Strategy

review, combined with replacing natural gas-driven

pneumatic devices with compressed air. These activities

have resulted in a 39% year-over-year reduction in absolute

Scope 1 methane emissions to 420 thousand MT CO2e from

686 thousand MT CO2e in 2022. Our Scope 1 methane

intensity improved more than 30% year-over-year to 0.8 MT

CO2e/ MMcfe and contributes to a three-year cumulative

reduction in methane intensity of ~50%.

METHANE INTENSITY LEVELS (2020-2023) vs.

DEFINED TARGETS

03_426107-1_bar_methane-intensity-levels-vs-defined-targets.jpg

Carbon dioxide emissions now account for 73% of our year-

end 2023 total Scope 1 emissions portfolio, an increase from

the prior year’s 62% of Scope 1 emissions though not

surprising given our near-term focus and success on

reducing methane emissions. Year-over-year absolute

Scope 1 CO2 emissions increased by approximately 10

thousand MT CO2 to 1,140 thousand MT CO2. A majority of

Diversified's CO2 emissions are generally attributable to

compressors and vehicle fuel. For 2023, this slight increase

in CO2 emissions was largely attributable to an increase in

liquid fuel emissions as a function of increased produced

water hauling associated with a Central Region acquisition

during the year and refined calculation methodologies.

Nitrous oxide remains an immaterial component of our

overall GHG emissions, totaling just one thousand MT CO2e

in 2023. Further, our location-based Scope 2 GHG emissions

remained largely unchanged year-over-year at ~61 thousand

MT CO2e. As such, the primary drivers of the net reduction

in total absolute Scope 1 and Scope 2 GHG emissions were

the aforementioned significant methane emission

reductions in fugitives and pneumatics, as reflected in the

14% decline from 1,879 thousand MT CO2e in 2022 to 1,622

thousand MT CO2e in 2023. With this reduction, our overall

Scope 1 and Scope 2 GHG emissions intensity declined 9%

from 3.4 MT CO2e/MMcfe in 2022 to 3.1 MT CO2e/MMcfe at

year-end 2023.

60	Diversified Energy Company PLC Annual Report and Form 20-F2023

YEAR-OVER-YEAR CHANGE IN SCOPE 1 AND 2 EMISSIONS

WATER USAGE

Due to the geographic locations of our assets and the

nature of our business model aimed at acquiring and

operating existing wells rather than drilling new wells, we

do not consider water availability to be a material climate-

related risk for our company. Further, according to the

World Resources Institute’s Aqueduct Water Risk Atlas,

99% of Diversified’s operations are located in states

classified as Low Overall Water Risk areas, using the oil and

gas industry-specific weighting scheme which is most

relevant for our business. At present we have therefore not

set ourselves specific targets regarding water usage.

INCENTIVIZING EMISSIONS

REDUCTION PERFORMANCE

Our commitment to reducing our GHG emissions is

reflected in our executive compensation plans which

include sustainability and climate-related targets.

An ESG-related performance component was first assigned

to a portion of the Executive Directors’ short-term incentive

plan (“STIP”) in 2020. Since then, our Remuneration

Committee and the Board have increased the ESG-related

percentage from 10% to 30%. ESG-related metrics were

also added to Executive Directors’ long-term incentive plan

(“LTIP”) first in 2022 and continue presently through 2024.

For both the STIP and LTIP, a portion of those ESG-related

metrics are specifically climate-related targets tied to

tactical methods to achieve further methane emission

reductions in our journey toward net zero in 2040, and thus

these short- and long-term incentive compensation metrics

are also applicable to members of senior leadership who

play an active role in executing these tactical methods.

	2020	2021	2022	2023	2024
STIP	10%	25%	30%	30%	30%
LTIP	N/A	N/A	20%	20%	20%

CONCLUSION

We recognize that the energy transition is a challenging

and complex global issue. However, Diversified continues to

prioritize its ambitious goals of reducing the carbon

intensity of its operations. With sustainability deeply

embedded in every aspect of our organization, we remain

steadfast in integrating climate considerations into our

company culture and decision-making processes.

We have assessed the impact of transition and physical

climate risks on our portfolio. The size and scope of market-

related climate risks were assessed and quantified through

scenario analysis, showing the resilience of our portfolio

even in the Net Zero scenario. Our qualitative assessment

of physical risks, such as extreme rainfall, hurricanes, water

stress, and heat stress, showed we are well-positioned to

mitigate and adapt to these risks, even in a more extreme

‘hothouse world’ scenario, associated with a temperature

increase of 4.3°C by 2100.

Our pragmatic approach to emission reductions, with a

near- and mid-term focus on de-methanization of our

operations, has yielded outstanding results with our 2030

methane intensity reduction target being achieved seven

years ahead of schedule - though we will not slow in our

efforts to capture further emission reductions as we move

forward. Our mission to achieve our long-term target of net

zero in 2040 continues, emboldened by the achievements

we have already made in reducing the methane intensity of

our operations. As we work toward our net zero targets, we

are committed to keeping environmental stewardship at the

forefront of our strategic decision-making.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	61

Managing Our Footprint

Diversified’s commitment to environmental stewardship

is focused on our responsible management of the natural

resources located within the communities we serve, the

safe and permanent retirement of end-of-life assets, our

efficient use of water, and the protection of biodiversity.

Our efforts to manage our environmental footprint start

with Diversified employees, who leverage their expertise

alongside innovative and proven solutions to help

reduce any potential negative impacts resulting from

our operations.

In addition to the previous GHG emissions and air quality

data and accompanying discussion within our

aforementioned TCFD disclosures, below are a number of

environmentally-focused areas within our footprint that are

relevant to our 2023 actions.

WELL RETIREMENT

Through our wholly-owned subsidiary, Next LVL Energy,

Diversified is a leader in well retirement in Appalachia. Next

LVL retires not only end-of-life wells owned by Diversified,

but also wells owned by other oil and gas operators in

Appalachia and abandoned wells with no current owner

that are the responsibility of the state. Further, Next LVL

serves as manager of the federal orphan well retirement

programs in southern Ohio.

ACTUAL WELLS RETIRED

1253

DEC wells(a)	Total wells, including<br><br>3rd party(a)

(a)Inclusive of 14 and 21 Central Region wells retired during 2022

and 2023, respectively

We retired 201 Diversified wells in Appalachia in 2023,

exceeding our stated objective for the year and significantly

exceeding annual requirements as per our existing state

agreements. We also retired 21 Diversified owned wells in

our Central Region states, bringing total retired company

wells to 222 in 2023.

During the year, the Next LVL team directly retired or

managed the retirement of 182 third-party wells, including

148 state and federal orphan wells and 34 wells for other

third-party operators. When considering both Diversified

and third-party retirements, we plugged a total of 404

wells during the year.

In its first full year of operation under Diversified’s

ownership, Next LVL’s expanded retirement capabilities

now include 14 teams and 17 rigs, well positioning the Group

to remain one of Appalachia’s largest and most active asset

retirement companies. Responsibly retiring end-of-life

assets is an integral part of our environmental stewardship

strategy. Included in this strategy are a rig utilization

optimization program, or a streamlined workflow that

affords more efficient movement of vehicles and equipment

thus reducing the plausibility of safety incidents while

simultaneously reducing vehicles emissions - and bespoke

well pad restoration and biodiversity protections while

retiring the wells and restoring the site.

WATER MANAGEMENT

Water is a finite and essential resource and thus,

responsible water withdrawal, use, and disposal is

important for our environmental performance. Our

operations are primarily located within areas that qualify as

Low Overall Water Risk, with only 1% located in areas that

have Low to Medium Overall Water Risk and none in areas

beyond Medium Risk, as assigned by the World Resources

Institute’s Aqueduct Water Risk Atlas. Even so, we apply

the same principles of operational efficiency and best

practice to our water use that we apply across our business,

with the goal to: (i) limit freshwater use, (ii) manage our

produced water, and (iii) expand recycling and reuse of

produced water.

Our differentiated business model significantly decreases

our reliance on water and therefore on freshwater

withdrawal, thus alleviating an environmental concern

material to many of our peers engaged in new

development. Given the location of our operations in low

water risk areas, no freshwater was withdrawn in high or

extremely high water stressed areas in 2023.

In 2023, we decreased our annual total water use to less

than one million barrels, or nearly 70% less than the prior

year, primarily as a result of decreased water consumption

for contracted drilling and hydraulic stimulation activities

for third parties during the year. Our own water

consumption is largely related to domestic use and various

well operations, including certain well treatments and asset

retirement activities. This decline in water consumption as

compared to our total gross production resulted in a

significant improvement in our year-over-year water

consumption intensity, as reflected below.

WATER CONSUMPTION INTENSITY(b)

(Bbl of Water per Boe Gross Production)

4425

(b)To improve year-over-year comparability, 2021 and 2022

metrics were revised to reflect updated reporting assumptions

for domestic water use

62	Diversified Energy Company PLC Annual Report and Form 20-F2023

The main waste associated with our operations is produced

water, a naturally occurring by-product from the

production of natural gas and oil. Therefore, most of our

efforts in water management focus on the handling and

disposal of produced water given the potential

environmental implications of the same. During 2023, our

produced water increased 34% year-over-year to 83

thousand barrels per day, due primarily to our increasing

presence in the Central Region through acquisition.

Our framework for managing produced water effluents

aims to first limit any environmental impacts and to

increase the safety of employees, contractors and

surrounding communities. Then, we focus on operational

efficiencies to reduce waste water, which may include

recycling and reuse efforts as well as seeking innovative

approaches or technologies which can evaporate water

from the production stream to reduce total produced

water or extract heavy elements from the produced water

to allow the now distilled water to be released into

water streams.

SPILL PREVENTION & MANAGEMENT

As an integral aspect of our environmental management

program, Diversified is committed to effectively preventing

spills across our operations. Our strategic approach to spill

prevention includes (i) maximizing the use of well-

maintained pipelines to transport produced liquids, (ii)

utilizing continuous monitoring and automated data

collection where applicable to inform our liquids decision-

making, and (iii) removing out of service or degraded

equipment which could inadvertently contribute to spills.

Our spill intensity rate improved 64% year-over-year largely

as a result of the creation and empowerment of a Spill

Prevention Focus Group in 2023 who developed and

effectuated a plan to better mitigate and manage spill

incidents, starting with a root cause analysis and action

process that included informed data collection and

increased training. Additional contributory actions included

prevention and mitigation awareness from our integrated

operations centers, the increased frequency of equipment

inspections and the use of sacrificial anodes to lower the

rate of naturally occurring corrosion in tanks.

SPILL INTENSITY

(Bbl of Spills per MBbl Gross Liquids Production)

6803

BIODIVERSITY

At Diversified, we are committed to safeguarding nature

and conserving biodiversity and ecosystems. We prioritize

responsible stewardship of our leaseholds and assets, and

focus on (i) minimizing environmental disruption though

our “Avoid, Mitigate, Restore and Offset” approach, (ii)

protecting sensitive species, habitats, and waterways, and

(iii) enhancing biodiversity and ecosystems within our

operational footprint. We achieve this through strong

oversight, risk management and standardized procedures,

recognizing that biodiversity protection is central to our

sustainable operations.

As part of our zero net deforestation goal and biodiversity

commitment, our 2023 efforts included a wide spectrum of

ecosystem enhancement activities, starting with bespoke

well pad restoration following well retirements for both

Diversified and third parties. For our largest project in 2023,

we partnered with West Virginia State University and its

Extension Service, along with over 500 individual

volunteers, to enable the planting during the year of nearly

11,000 bare-root seedlings and containerized trees in

municipal parks, underserved neighborhoods, degraded

forests, university campuses, and more.

Separately, we maximized the use of existing rights of way to

avoid potential stream and wetlands impacts during pipeline

extension work and effectuated projects independently

identified and developed by our summer intern which

included building and installing woodpecker houses in

various locations within our West Virginia footprint.

Safety in Focus

‘Safety-No Compromises’ has been and will continue to be

our utmost daily operational priority. While safety is

inherently the primary functional responsibility of the EHS

team, we recognize that safety is every employee’s

responsibility and priority - no matter the employee’s

location, position or job function. We recognize that

comprehensive and effective management practices

underpin the safety of our employees.

We take a data-driven approach to safety that includes an

electronic dashboard which contains key EHS metrics and is

readily accessible by all employees at any time. Thus, our

approach to safety training for our employees is both

preventative and responsive, utilizing the current and

historical results and trends from this dashboard -

partnered with amnesty-based Good Catch/Near Miss

reporting, computer-based and fit-for-purpose training, and

root cause analysis - to drive our safety training practices

and protocol as we work diligently to uphold a zero-harm

working environment.

PERSONAL SAFETY

While we take this approach to keep safety top of mind for

employees while on the job and despite an 84% increase in

Good Catch/Near Miss reporting, 2023 was a challenging year

for personal safety performance. We recorded a Total

Recordable Incident Rate (“TRIR”) of 1.28, up 75% from the

0.73 recorded in 2022 and higher than our 2023 target of 1.03.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	63

This year’s incident rate was driven primarily by an increase

in the total number of incidents, which were attributable in

part to short service employees with less than one year of

service under Diversified’s safety culture, which we are

seeking to address through our safety programs.

As with any incident and no matter the severity, our desire

for a zero harm working environment and our data-driven

approach to change management encourage us to (i) take

appropriate time to review the circumstances, causes and

corrective actions of these incidents and (ii) use these

results as a catalyst for improving forward

safety performance.

Our lessons learned to date in the review of our 2023

incidents reinforce what we already know - the task of

promoting safety is never finished - and highlight where our

safety program needs improvement, specifically in our

accountability and corrective action following an incident.

We have created a more robust work-flow for

accountability for safety incidents and formed a task force

to evaluate causal factors. So far, we have identified

opportunities for increased instruction for front line and

mid-level managers. and we will utilize the efforts of our

task force to drive additional, appropriate

program improvements.

Moving forward in 2024, while we will continue to promote

our Good Catch/Near Miss amnesty reporting program, we

are also updating our personal safety metrics to include

both TRIR and a severity rate, as measured by Lost Time

Incident rate, to provide enhanced clarity to our

safety performance.

TRIR

Per 200,000 work hours

2964

DRIVER SAFETY

Our field operations span across nine states, and this

geographic dispersion means employees may spend

significant time traveling on the roads, as evidenced by the

more than 24 million miles driven during the year. For this

reason, improving driver safety means reducing both miles

driven, which we accomplish in part through our remote

monitoring programs and efficient well tender routing, and

the accidents that occur during those miles. We seek zero

preventable motor vehicle accidents (“MVA”) during the

calendar year, and aim to incentivize accident-free driving

by offering our field teams annual safe driving awards and

leveraging our MVA metric in a portion of executive and

senior leadership short-term compensation.

Our 2023 MVA is 0.55 incidents per million miles driven, a

20% improvement from the 0.69 recorded in 2022.

VEHICLE SAFETY

Vehicle Incidents (“MVA”)

883

MVA	—	Miles Driven

PIPELINE AND PROCESS SAFETY

We operate a full complement of natural gas production,

gathering, transmission, and storage assets, including

thousands of miles of pipeline. To keep employees, our

communities, and the environment safe and protected, we

deploy rigorous monitoring and safety measures, engage in

regular maintenance, focus on operator training, maintain

well-documented operational and safety records, and utilize

state of the art technologies to aerially survey our systems.

Reflective of our commitment to asset integrity

management, during 2023 we were audited by 16 various

state and federal regulatory agencies and received zero

non-compliance citations with civil penalties for our

operational assets and compliance programs.

64	Diversified Energy Company PLC Annual Report and Form 20-F2023

Our Employees

We are committed to building a workplace that seeks to

attract and retain a talented and diverse staff by providing

attractive jobs with competitive salaries and meaningful

benefits, fostering a unified company culture, offering

equitable growth and development opportunities, and

creating a collaborative and enjoyable work environment

where all employees feel valued and supported in the work

they do.

Though our various operations encompass distinct

activities, we view our corporate and individual employee

actions through the lens of a single, unified OneDEC

approach that drives a culture of operational excellence

fostered through the integration of people and the

standardization of processes and systems. This OneDEC

approach supports and encourages company-wide

initiatives by ensuring alignment of our corporate and

sustainability goals with individual or collaborative action

supported by financial investment and well understood

principles and policies.

Regarding these principles and polices, during the year we

refreshed our Employee Relations Policy which defines

Diversified’s role in prioritizing employee well-being while

promoting an equal opportunity work environment. We also

updated our Employee Handbook to include new policies

and programs that offer additional opportunities and

benefits for employees. Finally, we developed a new

employee-specific Code of Business Conduct & Ethics

which serves as a framework for ethical decision-making,

helps ensure that all employees understand the

expectations and consequences of their actions, and

creates a safe, respectful and professional work

environment for all employees.

EMPLOYEE ENGAGEMENT

During the year, we capitalized on various opportunities to

promote employee engagement with members of

management and the Board. For example, executive

management held town hall meetings and in-the-field

interactions with employee groups, providing a platform for

the employees to receive direct updates on corporate

initiatives and developments and to ask questions directly

of executive and senior management. The Board’s Non-

Executive Director Employee Representative, Ms. Sandra

(Sandy) Stash, accompanied our Board Chairman in the fall

of 2023 on an asset and employee field visit in Texas,

meeting with employees to ensure the views of the

workforce are considered by the Directors. The Employee

Representative role was established in compliance with the

UK Corporate Governance Code, and 2023 was the third

full year of Ms. Stash’s tenure in this regard.

The valuable feedback from these meetings, along with that

resulting from our corporate-wide Employee Experience

Survey, is used to strengthen future employee engagement

and initiatives. We also regularly conduct new hire surveys

regarding the onboarding process as well as exit

interviews, both important tools to further improve

employee experiences.

In line with industry standards in the country of employment,

our employees maintain a range of relationships with union

groups. We have not previously experienced labor-related

work stoppages or strikes and believe that our relations with

our employees are satisfactory.

WORKFORCE DIVERSITY

The vast majority of our employee base at December 31,

2023 consists of production employees which includes

our upstream, midstream, and asset retirement field

personnel. All other employee positions, including back

office, administrative and executive positions, comprise

production support roles. Since inception of the Group, and

in alignment with our U.S.-based assets, all employees are

located in the U.S.

At Diversified, 11% of our total workforce at year-end was

made up of females (as self-reported), slightly higher than

the prior year-end and, in part, a function of our hiring

practices in 2023 where we hired female candidates at a

higher rate than female applications received (17% versus

14%, respectively, as self-reported). Ethnically diverse hiring

continues to be a focus. Our applicant data reflects that we

often have the least minority applicants per available job

opening in areas where we have some of the most available

openings. Likewise, we see a large number of minority

applications in a few areas where we have the least number

of annual openings. As always, we seek to enhance the

diversity of our employee base, ensuring our local

workforce mirrors the local population diversity, while also

striving to hire the best candidate for the position,

regardless of diversity characteristic.

At December 31, 2023, Senior Management, including the

executive committee and direct reports and excluding the

Executive Director, consisted of 103 employees, including

35 females (34%) and 68 males (66%).

At Diversified, we are dedicated to actively fostering an

environment of welcoming and belonging throughout all

facets of our business while demonstrating our company

principle to “value the dignity and worth of all individuals.”

Therefore, we utilize our talent acquisition team to seek and

develop programs and opportunities that allow us to

increase our diversity when hiring.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	65

2023 PRODUCTION EMPLOYEES	2023 PRODUCTION SUPPORT EMPLOYEES
2022 PRODUCTION EMPLOYEES	2022 PRODUCTION SUPPORT EMPLOYEES

TRAINING & DEVELOPMENT

We are committed to building a workplace that fosters

equitable growth opportunities and encourages human

capital and career development for all employees. We offer

several development programs and trainings to promote

the professional growth of employees, including our

existing Educational Assistance Program that offers tuition

reimbursement for advanced training in an employee’s field

of focus or a field that facilitates promotion opportunities.

In 2023, the Group also piloted a new Leadership Impact

Training (“LIT”) program for 40 managers across the

organization. The LIT is a Franklin Covey facilitated program

which includes a 360° feedback assessment that will drive a

personalized leadership development program for each

participant to better prepare participants for expanded

future leadership roles at Diversified. Based on overwhelming

positive feedback on the program, the Group intends to

continue this leadership program in 2024 and to introduce a

new LinkedIn Learning development program for

approximately 500 employees which also includes

personalized professional development curriculums.

TALENT ACQUISITION & RETENTION

Attracting and retaining talented and diverse staff is key to

our success as a business, and we remain focused on

providing attractive jobs with competitive salaries.

including hiring locally to build our long-term pipeline of

talent. In 2023, most of our new hires were from the local

communities in which we operate. Our commitment to local

hiring is indicative of our larger dedication to supporting

economic development in the areas in which we work.

Further, our commitment to hiring a diverse workforce was

bolstered this year with three unconscious bias training

programs undertaken by 350+ managers and leaders to

help them recognize potential bias present during the

interview, recruiting and promotion processes.

In addition to providing development programs and

trainings to promote career development for existing

employees, our hiring efforts also include utilizing our

summer internship and scholarship programs as a potential

employment pipeline for diverse candidates. We were

pleased to expand our internship program this year to

include 18 interns, surpassing our 2023 goal of hiring 15

interns. These interns included 15 traditional summer interns

who worked in various departments within the Group while

the other three interns were part of a local community

college’s workforce development initiative that allows

students to take technical courses toward a degree while

gaining paid work experience in their field of study.

Our total corporate turnover rate in 2023 was 17.1%, a slight

decrease over the prior year’s turnover of 17.6%.

66	Diversified Energy Company PLC Annual Report and Form 20-F2023

Our Communities

SOCIO-ECONOMIC IMPACT

Diversified assumes a vital role in supporting communities

across our 10-state operational footprint. By providing our

communities with employment opportunities underpinned

by competitive salaries and excellent benefits, state and

local tax revenues, royalty payments, and other direct and

indirect investments, we contribute significantly to the

economies of these states and, in doing so, positively

impact the communities where we operate.

Since 2021, we have commissioned an independent third-

party to conduct an analysis on the collective direct and

indirect economic impact we have across our 10-state

footprint. The analysis leverages financial and other data

from across our operations to assess the net impact we

have at the local, state and national level, and allows us to

illustrate the value of our contributions to stakeholders and

other interested parties. In the last year alone, for example,

we have contributed more than one billion dollars to the

U.S. GDP when considering both the direct and ancillary

impacts of our operations.

For example, in calendar year 2023, we provided more than

$500 million in ancillary labor income and generated more

than 6,300 ancillary jobs. These ancillary jobs, when

coupled with the ~1,600 employees we had at year-end

2023, highlight Diversified’s total employment impact of

nearly 8,000 jobs during the year. Year-over-year

operational expenditures across our footprint also

increased, but more substantially in states like Texas where

we grew through acquisition in 2023, therefore leading to

significant increases in economic benefit through job

creation within that state.

Beyond these economic benefits, employees across our

states continue to contribute to their communities through

volunteerism and donations, and Diversified is committed

to supporting these efforts.

COMMUNITY OUTREACH AND ENGAGEMENT

We are privileged to live and work in the 10 states across

our operational footprint. We believe with that privilege

and social license to operate comes a responsibility to

support those very communities in which we live and work,

and we recognize the long-lasting positive impact we can

have on both our communities and our business by

giving back.

Through our Community Giving and Engagement program,

we support organizations that have a positive, direct

impact on our communities. During 2023, through our grant

program and other corporate initiatives, we contributed

$2.1 million to more than 120 different charitable, education

related, and community and stakeholder engagement and

outreach organizations, including significant contributions

in geographic regions with large percentages of diverse

and/or socio-economically disadvantaged populations. Our

program is established around three main focus areas and

with the ultimate goal to support community initiatives that

fall under one or more of these areas: (1) community

enrichment, (2) education and workforce development and

(3) the environment. During 2023, our financial and human

capital supported organizations that included childhood

education, with emphasis on STEM (science, technology,

engineering and math), secondary and higher education,

children and adult physical and mental health and wellness,

environmental stewardship and biodiversity, fine arts for

children, food banks and meal programs, military and

veteran support groups, community and volunteer first

responders, and local infrastructure.

In addition to supporting employee volunteerism with these

and other deserving organizations, in 2023 we officially

launched the dollar-to-dollar matching gift program,

providing a company match on employee contributions up

to $1,500 per employee per year, where we matched

nearly $100 thousand in donations from employees during

the year.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	67

Section 172 Companies Act Statement

In compliance with sections 172

(‘Section 172”) and 414CZA of the UK

Companies Act, the Board makes the

following statement in relation to the year

ended December 31, 2023:

Our stakeholders are the many individuals and

organizations that are affected by our operations and with

whom we seek to proactively and positively engage on a

regular basis. We strive to maintain productive, mutually

beneficial relationships with each stakeholder group by

treating all stakeholders with fairness and respect and by

providing timely and effective responses and information.

We maintain several communication methods that afford

two-way engagement with our stakeholder groups,

including personal contact via face-to-face or telephone

conversation, email exchange, company reports, press

releases, investor presentations or conference participation

and other company engagement.

As the owner and operator of long-life assets, we naturally

make decisions that consider the long-term success of

Diversified and value creation for our stakeholders.

Engaging with our stakeholders informs our decision-

making, including consideration of our long-term strategic

objectives and the activities that support these aims, such

as merger and acquisition diligence and the management of

climate risk.

The following table provides a summary of stakeholder

engagements from 2023.

OUR STAKEHOLDERS

	Employees	Action and Engagement<br><br>Our CEO and other executive management periodically<br><br>conduct town hall meetings and field visits to personally<br><br>and directly engage employees and to provide<br><br>opportunities for employees to have direct management<br><br>engagement. Our Board’s Non-Executive Director<br><br>Employee Representative, Sandra M. Stash, also<br><br>periodically engages with the workforce to receive<br><br>employee feedback on our business strategy, corporate<br><br>culture and remuneration policies, and shares this<br><br>feedback with the Board. The valuable feedback from<br><br>these meetings, along with that resulting from our<br><br>updated corporate-wide Employee Experience Survey, is<br><br>used to strengthen future employee engagement<br><br>and initiatives. We also regularly conduct new hire<br><br>surveys regarding the onboarding process and exit<br><br>interviews, both important tools to further improve<br><br>employee experiences.
We know our employees are our greatest asset and<br><br>therefore essential to our success and growth. We<br><br>recognize the need for a skilled and committed workforce,<br><br>with a diverse range of experience and perspectives, and<br><br>we value that diversity and the contribution it affords.<br><br>Key Areas of Focus<br><br>—Incident management<br><br>—Employee, driver and process safety<br><br>—Diversity and equal opportunity<br><br>—Employee development<br><br>—Workplace culture
	Communities	Action and Engagement<br><br>Through our formalized Community Giving and<br><br>Engagement Program and other corporate initiatives,<br><br>we provided approximately $2.1 million in financial<br><br>support to numerous organizations, including adult<br><br>and children’s health and well-being programs, local<br><br>food banks, secondary and higher educational<br><br>programs and initiatives, and municipal services<br><br>throughout our 10-state footprint. We were especially<br><br>pleased to support children’s initiatives which included<br><br>purchasing and distributing, for the third consecutive<br><br>year, more than 1,200 winter coats in the Central<br><br>Region through Operation Warm, and participating in<br><br>the U.S. Marine Corp Reserve Toys-for-Tots Christmas<br><br>gift program. We also supported the purchase of<br><br>back-to-school supplies for elementary classrooms<br><br>across our footprint and separately collected and<br><br>donated more than 4,200 books to local schools and<br><br>libraries. Further, we supported U.S. veteran-focused<br><br>programs that seek to promote mental health healing<br><br>and wellness among combat-wounded veterans or<br><br>those suffering with post-traumatic stress disorder.
We actively seek to support sustainable socio-economic<br><br>development in the communities in which we live and work<br><br>and aim to minimize any potential negative impacts from<br><br>our operations.<br><br>From personal and socio-economic investment to strategic<br><br>academic and educational support, our employees engage<br><br>and serve their local communities through effective<br><br>partnerships that make a real difference.<br><br>Key Areas of Focus<br><br>—Incident management<br><br>—Effective grievance mechanisms<br><br>—Environmental protection<br><br>—Socio-economic investment and outreach<br><br>—Local hiring
68	Diversified Energy Company PLC Annual Report and Form 20-F2023
---	---
	Land and Mineral Owners	Action and Engagement<br><br>During the year, our employees responded to nearly 34<br><br>thousand inquiries from our land and mineral owners<br><br>through our in-house call center and recorded ~800<br><br>personal visits with landowners. We also distributed<br><br>approximately $237 million in royalty payments<br><br>during 2023.
---	---	---
We seek to develop and maintain trusted relationships with<br><br>our land and mineral owners with the recognition that these<br><br>relationships are key to our business philosophy and ability<br><br>to achieve our operational goals.<br><br>Key Areas of Focus<br><br>—Royalty payments<br><br>—Incident management<br><br>—Effective grievance mechanisms<br><br>—Environmental protection
	Equity and Debt Investors	Action and Engagement<br><br>We regularly provide financial, operational and other<br><br>sustainability performance updates to our equity and debt<br><br>investors. These updates may be in the form of investor<br><br>relations presentations, press releases, website updates,<br><br>or direct calls and meetings, inclusive of the CEO, CFO,<br><br>COO, SVP-Investor Relations, SVP-Sustainability, SVP-<br><br>EHS and/or Board Chairman, as applicable. The Annual<br><br>General Meeting (“AGM”) also provides an opportunity for<br><br>all shareholders to engage with the Board and<br><br>Executive Management.<br><br>Our increasing participation in energy conferences,<br><br>industry events and non-deal roadshows has provided<br><br>added opportunities for discussions with current and<br><br>potential Credit Facility lenders and ABS investors<br><br>particularly interested in our sustainability and emissions<br><br>reductions strategies, activities and results. Reflective of<br><br>that interest by ABS investors and our commitment to<br><br>climate and operating targets, our recent ABS<br><br>transactions, inclusive of our sustainability-linked Credit<br><br>Facility, have included interest rate impacts tied to certain<br><br>of these sustainability targets.
We actively engage with our capital market partners,<br><br>financial institutions and rating agencies to support a full<br><br>understanding of our business and progress against our<br><br>strategic priorities.<br><br>Key Areas of Focus<br><br>—Emissions reductions<br><br>—Climate risk and energy transition<br><br>—Incident management<br><br>—Risk management<br><br>—Corporate Governance<br><br>—Financial stability<br><br>—Access to funding
	Governments and Regulators	Action and Engagement<br><br>Executive and operational management engage with<br><br>federal, state and local regulators to address legislative,<br><br>regulatory and operational matters important to our<br><br>business and our industry. With risk identification and<br><br>protection of the local environment and biodiversity in<br><br>mind, we proactively and fully engage all applicable<br><br>regulatory agencies before commencing a project to<br><br>ensure transparent dialogue during the completion and<br><br>approval of applicable environmental assessments and<br><br>related actions.<br><br>We also proactively and transparently engage with<br><br>regulatory agencies throughout the year to keep them<br><br>appraised of our operational and well retirement activities<br><br>and to provide objective and measurable progress<br><br>indicators. Our Next LVL well retirement subsidiary<br><br>supports company efforts to exceed annual state<br><br>plugging requirements while also supporting the well<br><br>retirement needs of other oil and gas operators in the<br><br>Appalachia Basin as well as the states in their respective<br><br>federal orphan well retirement programs.
We seek to develop and maintain positive relationships and<br><br>regular dialogue with various stakeholder groups within our<br><br>federal, state and local governments.<br><br>Key Areas of Focus<br><br>—Legal compliance<br><br>—Tax payments to governments<br><br>—Safe and efficient asset retirement<br><br>—Emissions reductions<br><br>—Risk management<br><br>—Environmental protection				Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	69
---	---	---	---	---
	Suppliers and Customers	Action and Engagement<br><br>We use local suppliers and vendors in each of the states<br><br>in which we conduct our operations. We engage the<br><br>expertise and capability of a leading supply chain risk<br><br>management firm to continuously screen and monitor<br><br>contractor safety performance and compliance through<br><br>stringent operating guidelines.<br><br>With a network of approximately 700 suppliers, this<br><br>real-time monitoring helps to ensure our suppliers are<br><br>providing us with the necessary product and service<br><br>quality to meet the expectations of our stakeholders and<br><br>support ongoing agreements with those suppliers who<br><br>satisfy our safety thresholds.<br><br>We delivered 821 MMcfepd in 2023 with no cited process<br><br>and pipeline safety events or associated civil penalties.<br><br>We continue to use our pipeline awareness programs to<br><br>provide relevant information and education to those who<br><br>interact with our assets or employees.
---	---	---
Our production is essential to supporting modern life. We<br><br>work hard to deliver environmentally-focused, responsibly<br><br>produced natural gas, NGLs and oil that satisfy regulatory<br><br>requirements and meet the energy demands of our local<br><br>communities and customers while supporting our<br><br>climate goals.<br><br>We strive to develop strong relationships with our suppliers<br><br>that are built on trust, transparency and quality products<br><br>and services.<br><br>Key Areas of Focus<br><br>—Incident management<br><br>—Process safety<br><br>—Procurement management<br><br>—Access to funding
	Joint Operating Partners	Action and Engagement<br><br>We fulfill our responsibility as operator by responsibly<br><br>managing the wells, ensuring payment of related<br><br>expenses, and distributing applicable revenues and<br><br>royalties from the wells’ commodity sales.
As operator, we work on behalf of our joint operating<br><br>partners to safely and efficiently manage the assets and<br><br>deliver our products.<br><br>Key Areas of Focus<br><br>—Access to funding<br><br>—Risk management<br><br>—Employee and process safety<br><br>—Accident prevention
	Industry Associations	Action and Engagement<br><br>Through our active participation and the sharing of<br><br>operating best practices, technical knowledge and<br><br>legislation updates, we believe that these associations<br><br>add value to our business, support our industry at large<br><br>and protect the interests of our stakeholders.<br><br>Collaborative engagements in these associations provide<br><br>us with a platform to help collectively advance the sector<br><br>and industry as a whole. Our leadership’s participation in<br><br>industry associations includes participation in national,<br><br>regional and state associations in West Virginia, Virginia,<br><br>Kentucky, Pennsylvania, Ohio, Oklahoma, Texas,<br><br>and Louisiana.<br><br>We are especially proud of employees’ involvement and<br><br>leadership roles in organizations like the Women’s Energy<br><br>Network of West Virginia which seeks to empower<br><br>women across the energy value chain and the recognition<br><br>of our efforts in receiving both the Industry Innovation<br><br>award (for use of innovative technologies in emissions<br><br>detection) and Individual Excellence award (for long-<br><br>standing, proven leadership in the industry) as conveyed<br><br>by the Virginia Department of Energy.
Recognizing the benefit of collective and collaborative<br><br>efforts among industry peers, we are actively involved in<br><br>leadership and other roles in industry associations within<br><br>the states in which we operate.<br><br>Key Areas of Focus<br><br>—Incident management<br><br>—Environmental protection<br><br>—Risk management<br><br>—Industry advocacy and leadership<br><br>—Accident prevention<br><br>—Employee and driver safety<br><br>—Landowner engagement				70	Diversified Energy Company PLC Annual Report and Form 20-F2023
---	---

Non-Financial & Sustainability Information Statement

This section of the Strategic Report constitutes our Non-Financial & Sustainability Information Statement, produced to comply

with the Non-Financial & Sustainability Reporting Directive requirements from sections 414CA and 414CB of the UK Companies

Act 2006.

The table below sets out where relevant information can be found within this Annual Report & Form 20-F. Additional

information will be available in our Sustainability Report or on our website at www.div.energy. Our Policies can be found on

our website at www.div.energy.

Reporting Requirement	Policies	Reference within this<br><br>Annual Report & Form 20-F	Page
Environmental Matters	Code of Business Conduct & Ethics	Retire Assets Safely and Responsibly and<br><br>Restore the Environment to its<br><br>Natural State	18
	EHS
	Climate	Our Approach to Sustainability	38
	Business Partners	TCFD	39
	Biodiversity	Managing Our Footprint	62
		Our Communities	67
		Our Approach to Governance	126
Employees	Employee Relations	A Differentiated Business Model	10
	Anti-Bribery & Corruption	Our Approach to Sustainability	38
	Compliance Hotline &<br><br>Whistleblowing	Our Employees	65
	Code of Business Conduct & Ethics	Our Approach to Governance	126
	Human Rights
	Securities Dealing
Human Rights	Code of Business Conduct & Ethics	A Differentiated Business Model	10
	Human Rights	Our Employees	65
	Modern Slavery	Our Approach to Governance	126
	Business Partners
Social Matters	Code of Business Conduct & Ethics	Our Strategy Supports Sustainability	37
	EHS	Our Approach to Sustainability	38
	Human Rights	TCFD	39
	Tax	Managing Our Footprint	62
		Our Employees	65
		Our Communities	67
		Our Approach to Governance	126
Anti-Corruption & Anti-Bribery	Anti-Bribery & Corruption	Our Approach to Sustainability	38
	Compliance Hotline &<br><br>Whistleblowing	Our Approach to Governance	126
Business Model	Code of Business Conduct & Ethics	Business Model	14
		Strategy	14
		Our Approach to Governance	126
Principal Risks and Uncertainties	Compliance Hotline &<br><br>Whistleblowing	Our Approach to Sustainability	38
		Risk Management Framework	91
		Our Approach to Governance	126
Non-Financial KPIs	Code of Business Conduct & Ethics	Meet or Exceed State Asset<br><br>Retirement Goals	21
	EHS
	Climate	Total Recordable Incident Rate	21
		Our Approach to Governance	126
Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	71
---	---	---	---	---
Reporting Requirement	Reference within this Annual Report & Form 20-F	Page
---	---	---
Board oversight of climate-related risks and<br><br>opportunities.	TCFD: Governance	39
Identifying, assessing and managing climate-related risks<br><br>and opportunities.	TCFD: Governance<br><br>TCFD: Risk Management	39<br><br>57
How processes for identifying, assessing and managing<br><br>climate-related risks are integrated into the overall risk<br><br>management process.	TCFD: Embedding Sustainability Across the Organization<br><br>TCFD: Management’s Role in Assessing & Managing<br><br>Climate-Related Risks & Opportunities<br><br>TCFD: The Cultural Shift Underpins Our Transition to Net<br><br>Zero<br><br>TCFD: Risk Management	39<br><br>40<br><br>41<br><br>57
Principal climate-related risk and opportunities arising in<br><br>connection with operations.	TCFD: Climate-Related Risks and Opportunities<br><br>TCFD: Climate-Related Risks<br><br>TCFD: Climate-Related Opportunities	43<br><br>43<br><br>48
Time periods by reference to which risks and<br><br>opportunities are assessed.	TCFD: Climate-Related Risks and Opportunities<br><br>TCFD: Climate-Related Risks<br><br>TCFD: Climate-Related Opportunities	43<br><br>43<br><br>48
Actual and potential impacts of the principal climate-<br><br>related risks and opportunities on the business model and<br><br>strategy.	TCFD: Climate-Related Risks and Opportunities<br><br>TCFD: Climate-Related Risks<br><br>TCFD: Climate-Related Opportunities	43<br><br>43<br><br>48
Analysis of the resilience of the business model and<br><br>strategy, taking into consideration different climate-<br><br>related scenarios.	TCFD: Portfolio Resilience<br><br>TCFD: Portfolio Impact	54<br><br>55
Targets used by the organization to manage climate-<br><br>related risks and to realize climate-related opportunities<br><br>and of performance against those targets.	TCFD: Our Net Zero Pathway: Outperforming Our Targets<br><br>TCFD: Metrics & Targets	42<br><br>58
KPIs used to assess progress against targets used to<br><br>manage climate-related risks and realize climate-related<br><br>opportunities and of the calculations on which those KPIs<br><br>are based.	TCFD: Reporting GHG Emissions<br><br>TCFD: Incentivizing Emissions Reduction Performance	59<br><br>61		72	Diversified Energy Company PLC Annual Report and Form 20-F2023
---	---

BGG Headshot - 2023.1.jpg

A Message from Our

Chief Financial Officer

“
I am very pleased to report that 2023<br><br>was an outstanding year for Diversified,<br><br>with record financial results and solid<br><br>operational performance from our<br><br>assets.

Financial Review

Before penning my first CFO letter after many years, I took

a few moments to go back through all of Diversified’s

annual reports since going public in 2017. It was satisfying,

though not surprising, to see the common threads of our

firm's strategy and values woven through those pages-

reliable production, stable cash flows, durable margins and

consistent shareholder distributions. As I look ahead, I

intend to reinforce a disciplined financial approach to our

business that will provide flexibility and resiliency

throughout commodity price cycles. Additionally, we will be

diligent in expense management while looking to drive

further capital efficiency improvements through

the business.

I am very pleased to report that 2023 was an outstanding

year for Diversified, with record financial results and solid

operational performance from our assets. Adjusted EBITDA

was above expectations and reached a record level for the

Group. An improvement of approximately 3% in our total

per unit operating expense helped to deliver margins that

were approximately 50% or better for the sixth straight

year, with 2023 coming in at approximately 52%.

2023 began with an accretive acquisition in the Central

Region, allowing the opportunity to capture operational

synergies while increasing exposure to the premium Gulf

Coast markets pricing and the long-term demand pull from

the growth in LNG markets.

Additionally, we commenced trading on the New York

Stock Exchange (NYSE), an important strategic milestone

for the Company. The U.S. listing will enhance trading

liquidity and facilitate increased ownership from U.S.

domestic equity funds.

We ended the year with a highly successful transaction that

was both value-enhancing and deleveraging. This

approximately $192 million asset sale resulted in an

approximate 10% reduction in net debt.

Moreover, we have once again demonstrated that our

disciplined acquisition strategy allows us to be selective

and thoughtful in our approach but unwavering in our quest

to extract value when the opportunity affords itself.

You will find the full financial results of our operations on

the following pages, which I hope will be helpful as you

review our performance.

We expect 2024 to be a year of transition for both the

world and Diversified. Macroeconomic and geopolitical

developments remain a concern in the short term, with

limited visibility on how inflation, as well as other

disruptions, might impact energy prices, particularly natural

gas prices. We move into 2024 in a sound financial position,

with a focus on further reducing our debt, investing in

accretive acquisitions, and providing returns to our

shareholders. It is shaping up to be another exceptional

year for Diversified, one in which we will focus on playing

offense and being opportunistic, as we have historically

found this commodity price backdrop to provide a

tremendous opportunity to creatively grow our business

and ultimately create value for shareholders.

I want to thank our shareholders, debt holders, banks,

analysts, rating agencies, insurers, business partners, and

key advisors for their continued trust in Diversified and their

ongoing support to execute the proper measures to

strengthen our company and be in the best position to take

advantage of the opportunities we see ahead. I also want to

thank all of our dedicated, caring employees that are

focused on the safe production of American energy and are

also focused on continuing to deliver superb results for

their team members and our shareholders.

Bradley G. Gray

President & Chief Financial Officer

March 19, 2024

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	73

OPERATING RESULTS

Key Factors Affecting Our Performance

Our financial condition and results of operations have been,

and will continue to be, affected by a number of important

factors, including the following:

Strategic Acquisitions

We have made, and intend to continue to make, strategic

acquisitions to solidify our current market presence and

expand into new markets. We have made the following

business combinations or asset acquisitions for a total

aggregate consideration of $1.1 billion during the years

ended December 31, 2023, 2022 and 2021, comprised of:

—March 2023: The Tanos II Assets Acquisition, in which we

acquired certain upstream assets and related

infrastructure in the Central Region;

—September 2022: The ConocoPhillips Assets Acquisition,

in which we acquired certain upstream assets and related

gathering infrastructure in the Central Region;

—July 2022: Certain plugging infrastructure in the

Appalachian Region;

—May 2022: Certain plugging infrastructure in the

Appalachian Region;

—April 2022:

—The East Texas Assets Acquisition, in which we

acquired working interests in certain upstream assets

and related facilities within the Central Region from a

private seller, in conjunction with Oaktree;

—Certain midstream assets, inclusive of a processing

facility, in the Central Region that was contiguous to

our East Texas assets;

—February 2022: Certain plugging infrastructure in the

Appalachian Region;

—December 2021: The Tapstone Acquisition, where we

acquired working interests in certain upstream assets,

field infrastructure, equipment and facilities within the

Central Region in conjunction with Oaktree;

—August 2021: The Tanos Acquisition, in which we

acquired working interests in certain upstream assets

field infrastructure, equipment and facilities in the

Central Region in conjunction with Oaktree;

—July 2021: The Blackbeard Acquisition, in which we

acquired certain upstream assets and related gathering

infrastructure in the Central Region;

—May 2021: The Indigo Acquisition, in which we acquired

certain upstream assets and related gathering

infrastructure in the Central Region;

Our strategic acquisitions may affect the comparability of

our financial results with prior and subsequent periods. We

intend to continue to selectively pursue strategic

acquisitions to further strengthen our competitiveness. We

will evaluate and execute opportunities that complement

and scale our business, optimize our profitability, help us

expand into adjacent markets and add new capabilities to

our business. The integration of acquisitions also requires

dedication of substantial time and resources of

management, and we may never fully realize synergies and

other benefits that we expect.

Recent Developments

On March 19, 2024 we announced we entered into a

conditional agreement to acquire Oaktree’s proportionate

interest in the previously announced Indigo, Tanos III, East

Texas and Tapstone acquisitions for an estimated gross

purchase price of $410 million before customary purchase

price adjustments. The transaction is expected to be funded

through a combination of existing and expanded liquidity,

the assumption of Oaktree’s proportionate debt of

approximately $120 million associated with the ABS VI

amortizing note and approximately $90 million in deferred

cash payments to Oaktree. Additional liquidity for the

transaction may be generated from non-core asset sales

and the potential issuance of a private placement preferred

instrument.

Segment Reporting

We are an independent owner and operator of producing

natural gas and oil wells with properties located in the

states of Tennessee, Kentucky, Virginia, West Virginia, Ohio,

Pennsylvania, Oklahoma, Texas and Louisiana. Our strategy

is to acquire long-life producing assets, efficiently operate

those assets to maximize cash flow, and then to retire

assets safely and responsibly at the end of their useful life.

Our assets consist of natural gas and oil wells, pipelines and

a network of gathering lines and compression facilities that

are complementary to our core assets. We acquire and

manage these assets in a complementary fashion to

vertically integrate and improve margins rather than

managing them as separate operations. Accordingly, when

determining operating segments under IFRS 8, we

identified one operating segment that produces and

transports natural gas, NGLs and oil in the United States.

Refer to Note 2 in the Notes to the Group Financial

Statements for a description of our segment reporting.

74	Diversified Energy Company PLC Annual Report and Form 20-F2023

RESULTS OF OPERATIONS

Please refer to the APMs section within this Annual Report & Form 20-F for information on how these metrics are calculated

and reconciled to IFRS measures. Discussion related to prior period results can be found in the Results of Operations section of

our 2022 Annual Report on our website at https://ir.div.energy/reports-announcements.

	Year Ended
	December 31, 2023	December 31, 2022	Change	% Change
Net production
Natural gas (MMcf)	256,378	255,597	781	—%
NGLs (MBbls)	5,832	5,200	632	12%
Oil (MBbls)	1,377	1,554	(177)	(11%)
Total production (MMcfe)	299,632	296,121	3,511	1%
Average daily production (MMcfepd)	821	811	10	1%
% Natural gas (Mcfe basis)	86%	86%
Average realized sales price<br><br>(excluding impact of derivatives settled in cash)
Natural gas (Mcf)	$2.17	$6.04	$(3.87)	(64%)
NGLs (Bbls)	24.23	36.29	(12.06)	(33%)
Oil (Bbls)	75.46	89.85	(14.39)	(16%)
Total (Mcfe)	$2.68	$6.33	$(3.65)	(58%)
Average realized sales price<br><br>(including impact of derivatives settled in cash)
Natural gas (Mcf)	$2.86	$2.98	$(0.12)	(4%)
NGLs (Bbls)	26.05	19.84	6.21	31%
Oil (Bbls)	68.44	72.00	(3.56)	(5%)
Total (Mcfe)	$3.27	$3.30	$(0.03)	(1%)
Revenue (in thousands)
Natural gas	$557,167	$1,544,658	$(987,491)	(64%)
NGLs	141,321	188,733	(47,412)	(25%)
Oil	103,911	139,620	(35,709)	(26%)
Total commodity revenue	$802,399	$1,873,011	$(1,070,612)	(57%)
Midstream revenue	30,565	32,798	(2,233)	(7%)
Other revenue	35,299	13,540	21,759	161%
Total revenue	$868,263	$1,919,349	$(1,051,086)	(55%)
Gain (loss) on derivative settlements<br><br>(in thousands)
Natural gas	$177,139	$(782,525)	$959,664	(123%)
NGLs	10,594	(85,549)	96,143	(112%)
Oil	(9,669)	(27,728)	18,059	(65%)
Net gain (loss) on commodity derivative<br><br>settlements(a)	$178,064	$(895,802)	$1,073,866	(120%)
Total revenue, inclusive of settled hedges	$1,046,327	$1,023,547	$22,780	2%
Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	75
---	---	---	---	---
	Year Ended
---	---	---	---	---
	December 31, 2023	December 31, 2022	Change	% Change
Per Mcfe Metrics
Average realized sales price
(including impact of derivatives settled in cash)	$3.27	$3.30	$(0.03)	(1%)
Midstream and other revenue	0.22	0.16	0.06	38%
LOE	(0.71)	(0.62)	(0.09)	15%
Midstream operating expense	(0.23)	(0.24)	0.01	(4%)
Employees, administrative costs and professional<br><br>services	(0.26)	(0.26)	—	—%
Recurring allowance for credit losses	(0.03)	—	(0.03)	(100%)
Production taxes	(0.21)	(0.25)	0.04	(16%)
Transportation expense	(0.32)	(0.40)	0.08	(20%)
Proceeds received from leasehold sales	0.08	0.01	0.07	700%
Adjusted EBITDA per Mcfe	$1.81	$1.70	$0.11	6%
Adjusted EBITDA Margin	52%	49%
Other financial metrics (in thousands)
Adjusted EBITDA	$542,794	$502,954	$39,840	8%
Operating profit (loss)	$1,161,051	$(671,403)	$1,832,454	(273%)
Net income (loss)	$759,701	$(620,598)	$1,380,299	(222%)	Year Ended
---	---	---	---	---
	December 31, 2022	December 31, 2021	Change	% Change
Net production
Natural gas (MMcf)	255,597	234,643	20,954	9%
NGLs (MBbls)	5,200	3,558	1,642	46%
Oil (MBbls)	1,554	592	962	163%
Total production (MMcfe)	296,121	259,543	36,578	14%
Average daily production (MMcfepd)	811	711	100	14%
% Natural gas (Mcfe basis)	86%	90%
Average realized sales price<br><br>(excluding impact of derivatives settled in cash)
Natural gas (Mcf)	$6.04	$3.49	$2.55	73%
NGLs (Bbls)	36.29	32.53	3.76	12%
Oil (Bbls)	89.85	65.26	24.59	38%
Total (Mcfe)	$6.33	$3.75	$2.58	69%
Average realized sales price<br><br>(including impact of derivatives settled in cash)
Natural gas (Mcf)	$2.98	$2.36	$0.62	26%
NGLs (Bbls)	19.84	15.52	4.32	28%
Oil (Bbls)	72.00	71.68	0.32	—%
Total (Mcfe)	$3.30	$2.51	$0.79	31%
Revenue (in thousands)
Natural gas	$1,544,658	$818,726	$725,932	89%
NGLs	188,733	115,747	72,986	63%
Oil	139,620	38,634	100,986	261%
Total commodity revenue	$1,873,011	$973,107	$899,904	92%
Midstream revenue	32,798	31,988	810	3%
Other revenue	13,540	2,466	11,074	449%
Total revenue	$1,919,349	$1,007,561	$911,788	90%
76	Diversified Energy Company PLC Annual Report and Form 20-F2023
---	---
	Year Ended
---	---	---	---	---
	December 31, 2022	December 31, 2021	Change	% Change
Gain (loss) on derivative settlements<br><br>(in thousands)
Natural gas	$(782,525)	$(263,929)	$(518,596)	196%
NGLs	(85,549)	(60,530)	(25,019)	41%
Oil	(27,728)	3,803	(31,531)	(829%)
Net gain (loss) on commodity derivative<br><br>settlements(a)	$(895,802)	$(320,656)	$(575,146)	179%
Total revenue, inclusive of settled hedges	$1,023,547	$686,905	$336,642	49%
Per Mcfe Metrics
Average realized sales price
(including impact of derivatives settled in cash)	$3.30	$2.51	$0.79	31%
Midstream and other revenue	0.16	0.13	0.03	23%
LOE	(0.62)	(0.46)	(0.16)	35%
Midstream operating expense	(0.24)	(0.23)	(0.01)	4%
Employees, administrative costs and professional<br><br>services	(0.26)	(0.22)	(0.04)	18%
Recurring allowance for credit losses	—	0.02	(0.02)	(100%)
Production taxes	(0.25)	(0.12)	(0.13)	108%
Transportation expense	(0.40)	(0.31)	(0.09)	29%
Proceeds received from leasehold sales	0.01	—	0.01	100%
Adjusted EBITDA per Mcfe	$1.70	$1.32	$0.38	29%
Adjusted EBITDA Margin	49%	50%
Other financial metrics (in thousands)
Adjusted EBITDA	$502,954	$343,145	$159,809	47%
Operating profit (loss)	$(671,403)	$(467,064)	$(204,339)	44%
Net income (loss)	$(620,598)	$(325,206)	$(295,392)	91%

(a)Net gain (loss) on commodity derivative settlements represents cash (paid) or received on commodity derivative contracts. This excludes

settlements on foreign currency and interest rate derivatives as well as the gain (loss) on fair value adjustments for unsettled financial

instruments for each of the periods presented.

FORWARD-LOOKING STATEMENT

This Annual Report & Form 20-F contains forward-looking statements that can be identified by the following terminology,

including the terms “may,” “might,” “will,” “could,” “would,” “should,” “expect,” “plan,” “anticipate,” “intend,” “seek,” “believe,”

“estimate,” “predict,” “potential,” “continue,” “contemplate,” “possible,” or the negative of these terms or other variations or

comparable terminology, or by discussions of strategy, plans, objectives, goals, future events or intentions. These forward-

looking statements include all matters that are not historical facts. They appear in a number of places throughout this Annual

Report & Form 20-F and include, but are not limited to, statements regarding our intentions, beliefs or current expectations

concerning, among other things, our results of operations, financial positions, liquidity, prospects, growth, strategies and the

natural gas and oil industry. By their nature, forward-looking statements involve risk and uncertainty because they relate to

future events and circumstances.

Forward-looking statements are not guarantees of future performance and the actual results of our operations, financial

position and liquidity, and the development of the markets and the industry in which we operate, may differ materially from

those described in, or suggested by, the forward-looking statements contained in this Annual Report & Form 20-F. In addition,

even if the results of operations, financial position and liquidity, and the development of the markets and the industry in which

we operate are consistent with the forward-looking statements contained in this Annual Report & Form 20-F, those results or

developments may not be indicative of results or developments in subsequent periods. A number of factors could cause

results and developments to differ materially from those expressed or implied by the forward-looking statements including,

without limitation, general economic and business conditions, industry trends, competition, commodity prices, changes in

regulation, currency fluctuations, our ability to recover our reserves, changes in our business strategy, political and economic

uncertainty.

Forward-looking statements may, and often do, differ materially from actual results. Any forward-looking statements in this

Annual Report & Form 20-F speak only as of the date of this Annual Report & Form 20-F, reflect our current view with respect

to future events and are subject to risks relating to future events and other risks, uncertainties and assumptions relating to our

operations, results of operations, growth strategy and liquidity. Investors should specifically consider the factors identified in

this Annual Report & Form 20-F which could cause actual results to differ before making an investment decision. Subject to

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	77

the requirements of the Prospectus Rules, the Disclosure and Transparency Rules and the Listing Rules or applicable law, we

explicitly disclaim any obligation or undertaking publicly to release the result of any revisions to any forward-looking

statements in this Annual Report & Form 20-F that may occur due to any change in our expectations or to reflect events or

circumstances after the date of this Annual Report & Form 20-F.

PRODUCTION, REVENUE AND HEDGING

Total revenue in the year ended December 31, 2023 of $868 million decreased 55% from $1,919 million reported for the year

ended December 31, 2022, primarily due to a 58% decrease in the average realized sales price slightly offset by 1% higher

production. Including commodity hedge settlement gains of $178 million and losses of $896 million in 2023 and 2022,

respectively, total revenue, inclusive of settled hedges, increased by 2% to $1,046 million in 2023 from $1,024 million in 2022.

During the current year’s low commodity price environment, we have benefited from our ability to opportunistically elevate

our hedge floor during the elevated commodity market cycle in 2022. This enhancement in our weighted average hedge floor

helped us minimize the impact of the suppressed commodity pricing environment in 2023, during which we realized a

decrease in total commodity revenue of just $8 million, inclusive of settled hedges. Offsetting this slight decrease was an

increase of $12 million in total commodity revenue, inclusive of settled hedges, generated through increases in production. We

sold 299,632 MMcfe in 2023 versus 296,121 MMcfe in 2022. This increase in volumes sold was due to the March 2023 Tanos II

acquisition as well as the integration of a full year of production from the East Texas and ConocoPhillips acquisitions which

occurred in April and September of 2022, respectively.

The following table summarizes average commodity prices for the periods presented with Henry Hub on a per Mcf basis and

Mont Belvieu and WTI on a per Bbl basis:

	Year Ended
	December 31, 2023	December 31, 2022	$ Change	% Change
Henry Hub	$2.74	$6.62	$(3.88)	(59%)
Mont Belvieu	34.11	51.04	(16.93)	(33%)
WTI	77.62	93.53	(15.91)	(17%)	Year Ended
---	---	---	---	---
	December 31, 2022	December 31, 2021	$ Change	% Change
Henry Hub	$6.62	$3.84	$2.78	72%
Mont Belvieu	51.04	47.49	3.55	7%
WTI	93.53	68.26	25.27	37%

Refer to Note 5 in the Notes to the Group Financial Statements for additional information regarding acquisitions.

COMMODITY REVENUE

The following table reconciles the change in commodity revenue (excluding the impact of hedges settled in cash) for the year

ended December 31, 2023 by reflecting the effect of changes in volume and in the underlying prices:

(In thousands)	Natural Gas	NGLs	Oil	Total
Commodity revenue for the year ended December 31, 2021	$818,726	$115,747	$38,634	$973,107
Volume increase (decrease)	73,129	53,414	62,780	189,323
Price increase (decrease)	652,803	19,572	38,206	710,581
Net increase (decrease)	725,932	72,986	100,986	899,904
Commodity revenue for the year ended December 31, 2022	$1,544,658	$188,733	$139,620	$1,873,011
Volume increase (decrease)	4,717	22,935	(15,903)	11,749
Price increase (decrease)	(992,208)	(70,347)	(19,806)	(1,082,361)
Net increase (decrease)	(987,491)	(47,412)	(35,709)	(1,070,612)
Commodity revenue for the year ended December 31, 2023	$557,167	$141,321	$103,911	$802,399
78	Diversified Energy Company PLC Annual Report and Form 20-F2023
---	---

To manage our cash flows in a volatile commodity price environment and as required by our SPV-level asset-backed securities,

we utilize derivative contracts which allow us to fix the sales prices at a per unit level for approximately 83% of our production

to mitigate commodity risk. The tables below set forth the commodity hedge impact on commodity revenue, excluding and

including cash received for commodity hedge settlements:

(In thousands, except per<br><br>unit data)	Year Ended December 31, 2023
	Natural Gas		NGLs		Oil		Total Commodity
	Revenue	Realized $	Revenue	Realized $	Revenue	Realized $	Revenue	Realized $
		per Mcf		per Bbl		per Bbl		per Mcfe
Excluding hedge impact	$557,167	$2.17	$141,321	$24.23	$103,911	$75.46	$802,399	$2.68
Commodity hedge impact	177,139	0.69	10,594	1.82	(9,669)	(7.02)	178,064	0.59
Including hedge impact	$734,306	$2.86	$151,915	$26.05	$94,242	$68.44	$980,463	$3.27	(In thousands, except per<br><br>unit data)	Year Ended December 31, 2022
---	---	---	---	---	---	---	---	---
	Natural Gas		NGLs		Oil		Total Commodity
	Revenue	Realized $	Revenue	Realized $	Revenue	Realized $	Revenue	Realized $
		per Mcf		per Bbl		per Bbl		per Mcfe
Excluding hedge impact	$1,544,658	$6.04	$188,733	$36.29	$139,620	$89.85	$1,873,011	$6.33
Commodity hedge impact	(782,525)	(3.06)	(85,549)	(16.45)	(27,728)	(17.85)	(895,802)	(3.03)
Including hedge impact	$762,133	$2.98	$103,184	$19.84	$111,892	$72.00	$977,209	$3.30	(In thousands, except per<br><br>unit data)	Year Ended December 31, 2021
---	---	---	---	---	---	---	---	---
	Natural Gas		NGLs		Oil		Total Commodity
	Revenue	Realized $	Revenue	Realized $	Revenue	Realized $	Revenue	Realized $
		per Mcf		per Bbl		per Bbl		per Mcfe
Excluding hedge impact	$818,726	$3.49	$115,747	$32.53	$38,634	$65.26	$973,107	$3.75
Commodity hedge impact	(263,929)	(1.13)	(60,530)	(17.01)	3,803	6.42	(320,656)	(1.24)
Including hedge impact	$554,797	$2.36	$55,217	$15.52	$42,437	$71.68	$652,451	$2.51

Refer to Note 13 in the Notes to the Group Financial Statements for additional information regarding derivative

financial instruments.

EXPENSES

(In thousands, except per unit data)	Year Ended
	December<br><br>31, 2023	Per	December<br><br>31, 2022	Per	Total Change		Per Mcfe Change
		Per Mcfe		Per Mcfe	$	%	$	%
LOE(a)	$213,078	$0.71	$182,817	$0.62	$30,261	17%	$0.09	15%
Production taxes(b)	61,474	0.21	73,849	0.25	(12,375)	(17%)	(0.04)	(16%)
Midstream operating expenses(c)	69,792	0.23	71,154	0.24	(1,362)	(2%)	(0.01)	(4%)
Transportation expenses(d)	96,218	0.32	118,073	0.40	(21,855)	(19%)	(0.08)	(20%)
Total operating expenses	$440,562	$1.47	$445,893	$1.51	$(5,331)	(1%)	$(0.04)	(3%)
Employees, administrative costs<br><br>and professional services(e)	78,659	0.26	77,172	0.26	1,487	2%	—	—%
Costs associated with acquisitions(f)	16,775	0.06	15,545	0.05	1,230	8%	0.01	20%
Other adjusting costs(g)	17,794	0.06	69,967	0.24	(52,173)	(75%)	(0.18)	(75%)
Non-cash equity compensation(h)	6,494	0.02	8,051	0.03	(1,557)	(19%)	(0.01)	(33%)
Total operating and G&A expenses	$560,284	$1.87	$616,628	$2.09	$(56,344)	(9%)	$(0.22)	(11%)
Depreciation, depletion and<br><br>amortization	224,546	0.75	222,257	0.75	2,289	1%	—	—%
Allowance for credit losses(i)	8,478	0.03	—	—	8,478	100%	0.03	100%
Total expenses	$793,308	$2.65	$838,885	$2.84	$(45,577)	(5%)	$(0.19)	(7%)
Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	79
---	---	---	---	---
(In thousands, except per unit<br><br>data)	Year Ended
---	---	---	---	---	---	---	---	---
	December<br><br>31, 2022	Per	December<br><br>31, 2021	Per	Total Change		Per Mcfe Change
		Per Mcfe		Per Mcfe	$	%	$	%
LOE(a)	$182,817	$0.62	$119,594	$0.46	$63,223	53%	$0.16	35%
Production taxes(b)	73,849	0.25	30,518	0.12	43,331	142%	0.13	108%
Midstream operating<br><br>expenses(c)	71,154	0.24	60,481	0.23	10,673	18%	0.01	4%
Transportation expenses(d)	118,073	0.40	80,620	0.31	37,453	46%	0.09	29%
Total operating expenses	$445,893	$1.51	$291,213	$1.12	$154,680	53%	$0.39	35%
Employees, administrative<br><br>costs and professional<br><br>services(e)	77,172	0.26	56,812	0.22	20,360	36%	0.04	18%
Costs associated with<br><br>acquisitions(f)	15,545	0.05	27,743	0.11	(12,198)	(44%)	(0.06)	(55%)
Other adjusting costs(g)	69,967	0.24	10,371	0.04	59,596	575%	0.20	500%
Non-cash equity<br><br>compensation(h)	8,051	0.03	7,400	0.03	651	9%	—	—%
Total operating and G&A<br><br>expenses	$616,628	$2.09	$393,539	$1.52	$223,089	57%	$0.57	38%
Depreciation, depletion and<br><br>amortization	222,257	0.75	167,644	0.65	54,613	33%	0.10	15%
Allowance for credit losses(i)	—	—	(4,265)	(0.02)	4,265	(100%)	0.02	(100%)
Total expenses	$838,885	$2.84	$556,918	$2.15	$281,967	51%	$0.69	32%

(a)LOE includes costs incurred to maintain producing properties. Such costs include direct and contract labor, repairs and maintenance, water

hauling, compression, automobile, insurance, and materials and supplies expenses.

(b)Production taxes include severance and property taxes. Severance taxes are generally paid on produced natural gas, NGLs and oil

production at fixed rates established by federal, state or local taxing authorities. Property taxes are generally based on the taxing

jurisdictions’ valuation of the Group’s natural gas and oil properties and midstream assets.

(c)Midstream operating expenses are daily costs incurred to operate the Group’s owned midstream assets inclusive of employee and

benefit expenses.

(d)Transportation expenses are daily costs incurred from third-party systems to gather, process and transport the Group’s natural gas, NGLs and oil.

(e)Employees, administrative costs and professional services includes payroll and benefits for our administrative and corporate staff, costs of

maintaining administrative and corporate offices, costs of managing our production operations, franchise taxes, public company costs, fees

for audit and other professional services and legal compliance.

(f)We generally incur costs related to the integration of acquisitions, which will vary for each acquisition. For acquisitions considered to be a

business combination, these costs include transaction costs directly associated with a successful acquisition transaction. These costs also

include costs associated with transition service arrangements where we pay the seller of the acquired entity a fee to handle various G&A

functions until we have fully integrated the assets onto our systems. In addition, these costs include costs related to integrating IT systems

and consulting as well as internal workforce costs directly related to integrating acquisitions into our system.

(g)Other adjusting costs include items that affect the comparability of results or that are not indicative of trends in the ongoing business. These

costs consist of one time projects, contemplated transactions or financing arrangements, contract terminations, deal breakage and/or

sourcing costs for acquisitions, and unused firm transportation.

(h)Non-cash equity compensation reflects the expense recognition related to share-based compensation provided to certain key members of

the management team. Refer to Note 17 in the Notes to the Group Financial Statements for additional information regarding non-cash share-

based compensation.

(i)Allowance for credit losses consists of the recognition and reversal of credit losses. Refer to Note 14 in the Notes to the Group Financial

Statements for additional information regarding credit losses.

Operating Expenses

We experienced decreases in per unit operating expense of 3%, or $0.04 per Mcfe, resulting from:

—Higher per Mcfe LOE that increased 15%, or $0.09 per Mcfe, reflective of changes in our portfolio mix due to the higher cost

structure of the Central Region and our growing presence there. LOE includes cost from assets from our Tanos II acquisition

in March 2023 as well as a full year of expenses from the acquired East Texas Assets and ConocoPhillips assets acquired in

April and September 2022, respectively. Importantly, however, while per units costs increased, margins remained relatively

flat at 52%.

—Lower per Mcfe production taxes that declined 16%, or $0.04 per Mcfe were primarily attributable to a decrease in

severance taxes as a result of a decrease in revenue due to lower commodity prices; and

—Lower per Mcfe transportation expenses that declined 20%, or $0.08 per Mcfe, resulting from decreases in third-party

midstream rates that are tied to commodity pricing in the Central Region.

80	Diversified Energy Company PLC Annual Report and Form 20-F2023

General and Administrative Expense

G&A expense decreased primarily due to:

—A decrease in other adjusting costs due to the comparatively limited transactional activity in 2023 as compared to 2022.

From time to time, we incur costs associated with potential acquisitions that include deposits, rights of first refusal, option

agreement costs and hedging costs incurred in connection with the potential acquisitions. At times, due to changing macro-

economic conditions, commodity price volatility and/or findings observed during our deal diligence efforts, we incur

expenses of this nature as breakage and/or deal sourcing fees. In 2021, we paid $25 million in costs associated with a

potential acquisition and, due to decisions we made in the first quarter of 2022, we terminated the transaction and wrote off

$25 million in certain acquisition related costs related to these items.

—In February 2022, we paid $28 million to terminate a fixed-price purchase contract associated with certain Barnett volumes

acquired during the Blackbeard acquisition. The contract extended through March 2024 and, as a result of the termination,

we will realize more favorable pricing over this period. This transaction also positioned us to refinance these assets as part

of the ABS IV financing arrangement and allowed us to enhance our liquidity by eliminating the need for a $20 million letter

of credit on our Credit Facility. This transaction was classified in other adjusting costs.

Other Expenses

Depreciation, depletion and amortization (“DD&A”) increased due to higher depletion expense due to a 1% increase in

production attributable to an increased number of producing wells from acquisitions.

Allowance for credit losses increased due to the impact on anticipated credit losses on joint interest owner receivables has a

direct relationship with pricing and distributions to individual owners. As the pricing environment declined in 2023, the

underlying well economics did as well, and as a result, in 2023, we increased our reserve by $8 million.

Refer to Notes 5, 10, 11 and 13 in the Notes to the Group Financial Statements for additional information regarding acquisitions,

natural gas and oil properties, property, plant and equipment and derivative financial instruments, respectively.

DERIVATIVE FINANCIAL INSTRUMENTS

We recorded the following gain (loss) on derivative financial instruments in the Consolidated Statement of Comprehensive

Income for the periods presented:

(In thousands)	Year Ended
	December 31, 2023	December 31, 2022	$ Change	% Change
Net gain (loss) on commodity derivatives<br><br>settlements(a)	$178,064	$(895,802)	$1,073,866	(120%)
Net gain (loss) on interest rate swap(a)	(2,722)	(1,434)	(1,288)	90%
Gain (loss) on foreign currency hedges(a)	(521)	—	(521)	(100%)
Total gain (loss) on settled derivative<br><br>instruments	$174,821	$(897,236)	$1,072,057	(119%)
Gain (loss) on fair value adjustments of<br><br>unsettled financial instruments(b)	905,695	(861,457)	1,767,152	(205%)
Total gain (loss) on derivative financial<br><br>instruments	$1,080,516	$(1,758,693)	$2,839,209	(161%)	(In thousands)	Year Ended
---	---	---	---	---
	December 31, 2022	December 31, 2021	$ Change	% Change
Net gain (loss) on commodity derivatives<br><br>settlements(a)	$(895,802)	$(320,656)	$(575,146)	179%
Net gain (loss) on interest rate swaps(a)	(1,434)	(530)	(904)	171%
Gain (loss) on foreign currency hedges(a)	—	(1,227)	1,227	(100%)
Total gain (loss) on settled derivative<br><br>instruments	$(897,236)	$(322,413)	$(574,823)	178%
Gain (loss) on fair value adjustments of<br><br>unsettled financial instruments(b)	(861,457)	(652,465)	(208,992)	32%
Total gain (loss) on derivative financial<br><br>instruments	$(1,758,693)	$(974,878)	$(783,815)	80%

(a)Represents the cash settlement of hedges that settled during the period.

(b)Represents the change in fair value of financial instruments net of removing the carrying value of hedges that settled during the period.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	81

For the year ended December 31, 2023, we recognized a gain on derivative financial instruments of $1,081 million compared to

a loss of $1,759 million in 2022. Adjusting our unsettled derivative contracts to their fair values drove a gain of $906 million in

2023, as compared to a loss of $861 million in 2022.

For the year ended December 31, 2023, we recognized a gain on settled derivative instruments of $175 million as compared to

a loss of $897 million in 2022. The gain on settled derivative instruments relates to lower commodity market prices than we

secured through our derivative contracts. With consistent reliable cash flows central to our strategy, to protect our downside

risk we routinely hedge at levels that, based on our operating and overhead costs, provide a healthy margin even if it means

foregoing potential price upside.

Refer to Note 13 in the Notes to the Group Financial Statements for additional information regarding derivative

financial instruments.

GAIN ON BARGAIN PURCHASES

We recorded the following gain on bargain purchases in the Consolidated Statement of Comprehensive Income for the

periods presented:

(In thousands)	Year Ended
	December 31, 2023	December 31, 2022	$ Change	% Change
Gain on bargain purchases	$—	$4,447	$(4,447)	(100%)	(In thousands)	Year Ended
---	---	---	---	---
	December 31, 2022	December 31, 2021	$ Change	% Change
Gain on bargain purchases	$4,447	$58,072	$(53,625)	(92%)

In past years the E&P segment of the broader energy sector has been in a period of transition and rebalancing, thus creating

opportunities for healthy companies like ours to acquire high quality assets for less than their fair value. We have established a

track record of being disciplined in our bidding to acquire assets that meet our strict asset profile and are accretive to our

overall corporate value.

In 2022, we recognized a gain on bargain purchases of $4 million that was primarily a result of measurement period

adjustments associated with the 2021 Tapstone acquisition.

In 2021, we recognized a gain on bargain purchases of $58 million related to the acquisition of Tapstone and Tanos.

Gain on bargain purchases are not recorded for transactions that are accounted for as an acquisition of assets under IFRS 3,

Business Combinations (“IFRS 3”). Rather, the consideration paid is allocated to the assets acquired on a relative fair

value basis.

Refer to Note 5 in the Notes to the Group Financial Statements for additional information regarding acquisitions and bargain

purchase gain.

FINANCE COSTS

(In thousands)	Year Ended
	December 31, 2023	December 31, 2022	$ Change	% Change
Interest expense, net of capitalized and<br><br>income amounts(a)	$117,808	$86,840	$30,968	36%
Amortization of discount and deferred<br><br>finance costs	16,358	13,903	2,455	18%
Other	—	56	(56)	(100%)
Total finance costs	$134,166	$100,799	$33,367	33%	(In thousands)	Year Ended
---	---	---	---	---
	December 31, 2022	December 31, 2021	$ Change	% Change
Interest expense, net of capitalized and<br><br>income amounts(a)	$86,840	$42,370	$44,470	105%
Amortization of discount and deferred<br><br>finance costs	13,903	8,191	5,712	70%
Other	56	67	(11)	(16%)
Total finance costs	$100,799	$50,628	$50,171	99%
82	Diversified Energy Company PLC Annual Report and Form 20-F2023
---	---

(a)Includes payments related to borrowings and leases.

For the year ended December 31, 2023, interest expense of $118 million increased by $31 million compared to $87 million in

2022, primarily due to the increase in borrowings to fund our 2023 acquisition, incurring a full year of interest on borrowings

associated with the 2022 acquisitions and an increase in the weighted average interest rate on borrowings year-over-year.

As of December 31, 2023 and 2022, total borrowings were $1,325 million and $1,498 million, respectively. For the period ended

December 31, 2023, the weighted average interest rate on borrowings was 6.03% as compared to 5.51% as of December 31,

As of December 31, 2023, 87% of our borrowings now reside in fixed-rate, hedge-protected, amortizing structures

compared to 96% as of December 31, 2022.

Refer to Notes 5, 20, and 21 in the Notes to the Group Financial Statements for additional information regarding acquisitions,

leases and borrowings, respectively.

TAXATION

The effective tax rate is calculated on the face of the Statement of Comprehensive Income by dividing the amount of recorded

income tax benefit (expense) by the income (loss) before taxation as follows:

(In thousands)	Year Ended
	December 31, 2023	December 31, 2022	$ Change	% Change
Income (loss) before taxation	$1,000,344	$(799,502)	$1,799,846	(225%)
Income tax benefit (expenses)	(240,643)	178,904	(419,547)	(235%)
Effective tax rate	24.1%	22.4%			(In thousands)	Year Ended
---	---	---	---	---
	December 31, 2022	December 31, 2021	$ Change	% Change
Income (loss) before taxation	$(799,502)	$(550,900)	$(248,602)	45%
Income tax benefit (expenses)	178,904	225,694	(46,790)	(21%)
Effective tax rate	22.4%	41.0%

The differences between the statutory U.S. federal income tax rate and the effective tax rates are summarized as follows:

	Year Ended
	December 31, 2023	December 31, 2022	December 31, 2021
Expected tax at statutory U.S. federal income tax rate	21.0%	21.0%	21.0%
State income taxes, net of federal tax benefit	3.1%	1.2%	4.4%
Federal credits	—%	—%	15.4%
Other, net	—%	0.2%	0.2%
Effective tax rate	24.1%	22.4%	41.0%

For the year ended December 31, 2023, we reported a tax expense of $241 million, a change of $420 million, compared to a

benefit of $179 million in 2022 which was a result of the change in the loss before taxation and a change in the amount of tax

credits generated relative to the pre-tax loss. The resulting effective tax rates for the years ended December 31, 2023 and

2022 were 24.1% and 22.4%, respectively. The effective tax rate can be materially impacted by the recognition of the marginal

well tax credit available to qualified producers as noted in our 2021 effective tax rate. A marginal well tax credit was not

available in 2022 and this tax credit has not been announced for 2023. The federal government provides these credits to

encourage companies to continue operating lower-volume wells during periods of low prices to maintain the underlying jobs

they create and the state and local tax revenues they generate for communities to support schools, social programs, law

enforcement and other similar public services.

Refer to Note 8 in the Notes to the Group Financial Statements for additional information regarding taxation.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	83

OPERATING PROFIT, NET INCOME, ADJUSTED EBITDA AND EPS

(In thousands, except per unit data)	Year Ended
	December 31, 2023	December 31, 2022	$ Change	% Change
Operating profit (loss)	$1,161,051	$(671,403)	$1,832,454	(273%)
Net income (loss)	759,701	(620,598)	1,380,299	(222%)
Adjusted EBITDA	542,794	502,954	39,840	8%
Earnings (loss) per share - basic	$16.07	$(14.82)	$30.89	(208%)
Earnings (loss) per share - diluted	$15.95	$(14.82)	$30.77	(208%)	(In thousands, except per unit data)	Year Ended
---	---	---	---	---
	December 31, 2022	December 31, 2021	$ Change	% Change
Operating profit (loss)	$(671,403)	$(467,064)	$(204,339)	44%
Net income (loss)	(620,598)	(325,206)	(295,392)	91%
Adjusted EBITDA	502,954	343,145	159,809	47%
Earnings (loss) per share - basic	$(14.82)	$(8.20)	$(6.62)	81%
Earnings (loss) per share - diluted	$(14.82)	$(8.20)	$(6.62)	81%

For the year ended December 31, 2023, we reported net income of $760 million and basic EPS of $16.07 ($15.95 diluted EPS)

compared to net loss of $621 million and basic loss per share of $14.82 ($14.82 diluted loss per share) in 2022, an increase of

222% and 208%, respectively. We also reported an operating profit of $1,161 million compared with an operating loss of $671

million for the years ended December 31, 2023 and 2022, respectively. This year-over-year increase was primarily attributable

to a $2,839 million increase in gains on derivatives, a $40 million increased in gains on sale of assets, offset by a decrease in

gross profit of $1,048 million, $33 million more in finance costs, and $420 million more income tax expense as compared

to 2022.

Excluding the mark-to-market gain on long-dated derivative valuations, as well as other customary adjustments, we reported

adjusted EBITDA of $543 million for the year ended December 31, 2023 compared to $503 million for the year ended

December 31, 2022, representing an increase of 8% driven by our growth through the Tanos II acquisition in 2023 and a full

year of the 2022 East Texas Assets and ConocoPhillips acquisitions.

LIQUIDITY AND CAPITAL RESOURCES

Overview

Our principal sources of liquidity are cash generated from operations and available borrowings under our Credit Facility. To

minimize interest expense, we use our excess cash flow to reduce borrowings on our Credit Facility and as a result have

historically carried little cash on our Consolidated Statement of Financial Position as evidenced by our $4 million and $7 million

in cash and cash equivalents as of December 31, 2023 and 2022, respectively.

When we acquire assets to grow, we complement our Credit Facility with asset-backed debt securitized by certain natural gas

and oil assets, which are long-term, fixed-rate, fully-amortizing debt structures that better match the long-life nature of our

assets. These structures afford us low borrowing rates and also provide a visible path for reducing leverage as we make

scheduled principal payments. For larger value-adding acquisitions, and to ensure we maintain a leverage profile that we

believe is appropriate for the type of assets we acquire, we also raise proceeds through secondary equity offerings from time

to time.

We monitor our working capital to ensure that the levels remain adequate to operate the business with excess liquidity

primarily utilized for the repayment of debt or dividends to shareholders. In addition to working capital management, we have

a disciplined approach to managing operating costs and allocating capital resources, ensuring that we are generating returns

on our capital investments to support the strategic initiatives in our business operations.

Capital expenditures were $74 million for the year ended December 31, 2023 compared to $86 million for the year ended

December 31, 2022. This decrease in capital expenditures was primarily driven by the completion of wells in 2022 that were

under development by Tapstone at the time we closed that acquisition in 2021. While our March 2023 Tanos II acquisition also

contained wells under development at the time of acquisition, the capital expenditures needed for their development during

2023 was less significant than that required during 2022. We expect to meet our capital expenditure needs for the foreseeable

future from our operating cash flows and our existing cash and cash equivalents. Our future capital requirements will depend

on several factors, including our growth rate and future acquisitions, among other things.

With respect to our other known current obligations, we believe that our sources of liquidity and capital resources will be

sufficient to meet our existing business needs for at least the next 12 months. However, our ability to satisfy our working

capital requirements, debt service obligations and planned capital expenditures will depend upon our future operating

performance, which will be affected by prevailing economic conditions in the natural gas and oil industry and other financial

and business factors, some of which are beyond our control.

84	Diversified Energy Company PLC Annual Report and Form 20-F2023

Refer to Note 13 in the Notes to the Group Financial Statements for additional information regarding our hedging program to

mitigate the risk associated with future cash flow generation.

The table below represents our liquidity position as of December 31, 2023, 2022 and 2021.

	As of
(In thousands)	December 31, 2023	December 31, 2022	December 31, 2021
LESS: Cash	$3,753	$7,329	$12,558
Available borrowings under the Credit Facility(a)	134,817	183,332	222,263
Liquidity	$138,570	$190,661	$234,821

(a)Represents available borrowings under the Credit Facility of $146 million as of December 31, 2023 less outstanding letters of credit of $11

million as of such date. Represents available borrowings under the Credit Facility of $194 million as of December 31, 2022 less outstanding

letters of credit of $11 million as of such date. Represents available borrowings under the Credit Facility of $254 million as of December 31,

2021 less outstanding letters of credit of $32 million as of such date.

DEBT

Our net borrowings consisted of the following as of the reporting date:

	As of
(In thousands)	December 31, 2023	December 31, 2022
Credit Facility	$159,000	$56,000
ABS I Notes	100,898	125,864
ABS II Notes	125,922	147,458
ABS III Notes	274,710	319,856
ABS IV Notes	99,951	130,144
ABS V Notes	290,913	378,796
ABS VI Notes	159,357	212,446
Term Loan I	106,470	120,518
Other	7,627	7,084
Total debt	$1,324,848	$1,498,166
LESS: Cash	3,753	7,329
LESS: Restricted cash	36,252	55,388
Net debt	$1,284,843	$1,435,449

OUR CAPITAL EXPENDITURE PROGRAM

Our strategy to acquire and operate producing assets that generate adjusted EBITDA margins of approximately 50% allows us

to invest capital back into our operations. In addition, we have set goals to achieve “net zero” Scope 1 and Scope 2 emissions

by 2040 through new investments aimed at emissions reductions, such as investments in natural gas emissions detection

devices and conducting aerial scans of our assets.

The majority of our capital expenditures are focused on our midstream operations, which includes pipelines and compression,

while the remaining capital expenditures are focused on production optimization, technology, upstream operations, plugging

capacity expansion, fleet, emissions reductions, and when prudent, may include development activities targeted at replacing

production. Given our operational focus to acquire and operate mature conventional wells and unconventional wells with a

shallow decline rate, we do not incur the same level of large capital expenditures associated with drilling and completion

activities that would typically be incurred by other development focused exploration and production companies.

We have consistently targeted a disciplined leverage profile at or under 2.5 to 1.0 after giving effect to acquisitions and any

related financing arrangements. We believe this leverage range is supported by our differentiated business model, namely with

long-life, low-decline production providing resilient cash flows, and a strategic financial framework that is bolstered by

hedging and amortizing debt instruments. Our weighted-average hedge floor on natural gas production increased from $3.63

per Mcf as of December 31, 2022 to $3.87 per Mcf as of December 31, 2023.

Looking forward, we continue to seek to maximize cash flow. We plan to maintain our hedging strategy and take advantage of

market opportunities to raise the floor price of our risk management program. We will seek to retain our strategic advantages

in purposeful growth through a disciplined capital expenditure program that continues to secure low-cost financing that

supports acquisitive growth while maintaining low leverage and sufficient liquidity.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	85

ASSET RETIREMENT OBLIGATIONS

We continue to be proactive and innovative with respect to asset retirement. In 2017, after our LSE IPO, we proactively began

to meet with state officials to develop a long-term plan to retire our growing portfolio of long-life wells. Collaborating with the

appropriate regulators, we designed our retirement activities to be equitable for all stakeholders with an emphasis on

the environment.

During the year ended December 31, 2023 we accomplished the following:

—Expanded asset retirement operations from 15 rigs at December 31, 2022 to 17 rigs at December 31, 2023 increasing our

asset retirement capacity in Appalachia;

—Retired 222 wells, inclusive of our Central Region operations, outpacing calendar year 2022 activity when we retired 214

wells. These retirements were achieved one full year in advance of our stated goal to retire 200 wells per year by year-end

2023; and

—Retired 182 outside party wells, including 148 state and federal orphan wells and 34 wells for other operators.

This growth in our asset retirement capacity provides us with the ability to further integrate our asset retirement operations

and generate cost efficiencies across a broader footprint. It will also provide us with the ability to generate additional third-

party revenues by providing a suite of services to other production companies which can be utilized to help fund the cost

associated with our own asset retirement program. As a result, we aim to obtain a prudent mix of both cost reduction and

third-party revenues to maximize the benefits of our internal asset retirement program.

Our asset retirement program reflects our solid commitment to a healthy environment and the surrounding communities, and

we anticipate continued investment and innovation in this area. During 2024, we will continue our work to realize the vertical

integration benefits of expanded internal asset retirement capacity to reduce reliance on third-party contractors, reduce

outsource risk, improve process quality and responsiveness, and increase control over environmental remediation and costs.

The composition of the provision for asset retirement obligations at the reporting date was as follows for the

periods presented:

	Year Ended
(In thousands)	December 31, 2023	December 31, 2022	December 31, 2021
Balance at beginning of period	$457,083	$525,589	$346,124
Additions(a)	3,250	24,395	96,292
Accretion	26,926	27,569	24,396
Asset retirement costs	(5,961)	(4,889)	(2,879)
Disposals(b)	(17,300)	(16,779)	(16,500)
Revisions to estimate(c)	42,650	(98,802)	78,156
Balance at end of period	$506,648	$457,083	$525,589
Less: Current asset retirement obligations	5,402	4,529	3,399
Non-current asset retirement obligations	$501,246	$452,554	$522,190

(a)Refer to Note 5 in the Notes to the Group Financial Statements for additional information regarding acquisitions and divestitures.

(b)Associated with the divestiture of natural gas and oil properties. Refer to Note 5 in the Notes to the Group Financial Statements for

additional information.

(c)As of December 31, 2023, we performed normal revisions to our asset retirement obligations, which resulted in a $43 million increase in the

liability. This increase was comprised of a $28 million increase attributable to a lower discount rate as a result of slightly decreased bond

yields as compared to 2022 as inflation began to increase at a lower rate and $16 million in cost revisions based on our recent asset

retirement experiences. Partially offsetting these decreases was a $1 million change attributed to timing. As of December 31, 2022, we

performed normal revisions to our asset retirement obligations, which resulted in a $99 million decrease in the liability. This decrease was

comprised of a $145 million decrease attributable to the lower discount rate which was then offset by a $29 million reduction in anticipated

asset retirement cost. The remaining change was attributable to timing. The lower discount rate was a result of macroeconomic factors

spurred by the COVID-19 recovery, which reduced bond yields and increased inflation. Cost reductions are based on our recent asset

retirement experiences. As of December 31, 2021, we performed normal revisions to our asset retirement obligations, which resulted in a $78

million increase in the liability. This increase was comprised of a $109 million increase attributable to the lower discount rate which was then

offset by a $27 million reduction in anticipated asset retirement cost. The remaining change was attributable to timing. The lower discount

rate was a result of macroeconomic factors spurred by the COVID-19 recovery, which reduced bond yields and increased inflation. Cost

reductions are based on our recent asset retirement experiences.

The anticipated future cash outflows for our asset retirement obligations on an undiscounted and discounted basis were as set

forth in the tables below as of December 31, 2023, 2022 and 2021. When discounting the obligation, we apply a contingency

allowance for annual inflationary cost increases to our current cost expectations and then discount the resulting cash flows

using a credit adjusted risk free discount rate resulting in a net discount rate of 3.4%, 3.6% and 2.9% for the periods indicated,

86	Diversified Energy Company PLC Annual Report and Form 20-F2023

respectively. While the rate is comparatively small to the commonly utilized PV-10 metric in our industry, the impact is

significant due to the long-life low-decline nature of our portfolio. Although productive life varies within our well portfolio,

presently we expect all of our existing wells to have reached the end of their productive lives and be retired by approximately

2095, consistent with our reserve calculations which were independently evaluated by third-party engineers.

When evaluating our ability to meet our asset retirement obligations we review reserves models which utilize the income

approach to determine the expected discounted future net cash flows from estimated reserve quantities. These models

determine future revenues associated with production using forward pricing then consider the costs to produce and develop

reserves, as well as the cost of asset retirement at the end of a well’s life. These future net cash flows are discounted using a

weighted average cost of capital of 10% to produce the PV-10 of our reserves. After considering the asset retirement costs in

these models, our PV-10 was approximately $2.1 billion, $8.8 billion and $4.0 billion as of December 31, 2023, 2022 and 2021,

respectively, illustrating residual cash flows well beyond our retirement obligations.

As of December 31, 2023:

(In thousands)	Not Later Than<br><br>One Year	Later Than One<br><br>Year and Not Later<br><br>Than Five Years	Later Than<br><br>Five Years
				Total
Undiscounted	$5,402	$20,365	$1,778,876	$1,804,643
Discounted	5,402	17,975	483,271	506,648

As of December 31, 2022:

(In thousands)	Not Later Than<br><br>One Year	Later Than One<br><br>Year and Not Later<br><br>Than Five Years	Later Than<br><br>Five Years
				Total
Undiscounted	$4,529	$19,671	$1,673,905	$1,698,105
Discounted	4,529	17,314	435,240	457,083

As of December 31, 2021:

(In thousands)	Not Later Than<br><br>One Year	Later Than One<br><br>Year and Not Later<br><br>Than Five Years	Later Than<br><br>Five Years
				Total
Undiscounted	$3,399	$17,210	$1,594,853	$1,615,462
Discounted	3,399	13,675	508,515	525,589

CASH FLOWS

Our principal sources of liquidity have historically been cash generated from operating activities. To minimize financing costs,

we apply our excess cash flow to reduce borrowings on our Credit Facility. When we acquire assets to grow, we complement

our Credit Facility with long-term, fixed-rate, fully-amortizing debt structures that better match the long-life nature of our

assets. These structures afford us low borrowing rates and also provide a visible path for reducing leverage as we make

scheduled principal payments. For larger value-adding acquisitions, and to ensure we maintain a leverage profile that we

believe is appropriate for the type of assets we acquire, we will also raise equity proceeds through a secondary offering.

We monitor our working capital to ensure that the levels remain adequate to operate the business with excess cash primarily

being utilized for the repayment of debt or shareholder distributions. In addition to working capital management, we have a

disciplined approach to managing operating costs and allocating capital resources, ensuring that we are generating returns on

our capital investments to support the strategic initiatives in our business operations.

(In thousands)	Year Ended
	December 31, 2023	December 31, 2022	$ Change	% Change
Net cash provided by operating activities	$410,132	$387,764	$22,368	6%
Net cash used in investing activities	(239,369)	(386,457)	147,088	(38%)
Net cash provided by (used in) financing<br><br>activities	(174,339)	(6,536)	(167,803)	2,567%
Net change in cash and cash equivalents	$(3,576)	$(5,229)	$1,653	(32%)
Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	87
---	---	---	---	---
(In thousands)	Year Ended
---	---	---	---	---
	December 31, 2022	December 31, 2021	$ Change	% Change
Net cash provided by operating activities	$387,764	$320,182	$67,582	21%
Net cash used in investing activities	(386,457)	(627,712)	241,255	(38%)
Net cash provided by (used in) financing<br><br>activities	(6,536)	318,709	(325,245)	(102%)
Net change in cash and cash equivalents	$(5,229)	$11,179	$(16,408)	(147%)

Net Cash Provided by Operating Activities

For the year ended December 31, 2023, net cash provided by operating activities of $410 million increased by $22 million, or

6%, when compared to $388 million in 2022. The increase in net cash provided by operating activities was predominantly

attributable to the following:

—An increase in total revenue, inclusive of settled hedges, coupled with the decreases in expenses described above. This

increase in adjusted EBITDA was then offset by the increases in finance costs;

—Changes in working capital generated cash outflows, driven by decreasing accounts payable balances, accrued liabilities,

and distribution in suspense balances. These increases are a function of working capital turnover from the higher price

environment experienced in 2022 to the lower price environment in 2023.

Production, realized prices, operating expenses, and G&A are discussed above.

Net Cash Used in Investing Activities

For the year ended December 31, 2023, net cash used in investing activities of $239 million decreased by $147 million, or 38%,

from outflows of $386 million in 2022. The change in net cash used in investing activities was primarily attributable to

the following:

—A decrease in cash outflows of $138 million for acquisition, divestiture and disposal activity. Net cash outflows associated

with acquisitions, divestitures and disposals was $162 million during the year ended December 31, 2023 when compared to

$300 million for the year ended December 31, 2022. Refer to Note 5 and Note 11 in the Notes to the Group Financial

Statements for additional information regarding acquisitions, divestitures and disposals;

—Capital expenditures were $74 million for the year ended December 31, 2023 compared to $86 million for the year ended

December 31, 2022. This decrease in capital expenditures was primarily driven by the completion of wells in 2022 that were

under development by Tapstone at the time we closed that acquisition in 2021. While our March 2023 Tanos II acquisition

also contained wells under development at the time of acquisition, the capital expenditures needed for their development

during 2023 was less than that required during 2022.

Net Cash Provided by Financing Activities

For the year ended December 31, 2023, net cash used in financing activities of $174 million increased by $168 million as

compared to $7 million in 2022. This change in net cash used in financing activities was primarily attributable to the following:

—Credit Facility, ABS Note and Term Loan activity resulted in net repayments of $11 million (including $277 million in

repayments of amortizing debt) in 2023 versus net proceeds of $448 million in 2022, with much of the change attributable

to the issuance of the ABS III-VI Notes in 2022 which refinanced a portion of our Credit Facility by converting it to a fixed-

rate, hedge-protected, amortizing structure.

—An increase of $157 million in proceeds from equity issuances in 2023 that did not occur in 2022.

—A decrease of $12 million in restricted cash as a result of the establishment of the interest reserve required by our ABS III -

VI Notes that were issued in 2022. No similar notes were issued and consolidated into our financial statements in 2023,

—An increase of $99 million due to reduced hedge modifications associated with ABS notes in 2023 as compared to 2022,

—A decrease of $24 million in the repurchase of shares, inclusive of EBT repurchases, as there were no similar EBT

repurchases in 2023, and

—An increase of $25 million in dividends paid in 2023 as compared to 2022;

Refer to Notes 16, 18 and 21 in the Notes to the Group Financial Statements for additional information regarding share capital,

dividends and borrowings, respectively.

OFF-BALANCE SHEET ARRANGEMENTS

We may enter into off-balance sheet arrangements and transactions that give rise to material off-balance sheet obligations. As

of December 31, 2023 and December 31, 2022, our material off-balance sheet arrangements and transactions include operating

service arrangements of $11 million in letters of credit outstanding against our Credit Facility, respectively.

There are no other transactions, arrangements or other relationships with unconsolidated entities or other persons that are

reasonably likely to materially affect our liquidity or availability of capital resources.

88	Diversified Energy Company PLC Annual Report and Form 20-F2023

CONTRACTUAL OBLIGATIONS AND CONTINGENT LIABILITIES AND COMMITMENTS

We have various contractual obligations in the normal course of our operations and financing activities. Significant contractual

obligations as of the periods presented were as follows:

(In thousands)	Not Later Than<br><br>One Year	Later Than<br><br>One Year and<br><br>Not Later Than<br><br>Five Years	Later Than<br><br>Five Years
				Total
Recorded contractual obligations
Trade and other payables	$53,490	$—	$—	$53,490
Borrowings	200,822	864,264	259,762	1,324,848
Leases	10,563	20,559	—	31,122
Asset retirement obligation(a)	5,402	20,365	1,778,876	1,804,643
Other liabilities(b)	178,779	2,224	—	181,003
Off-Balance Sheet contractual obligations
Firm Transportation(c)	28,242	29,919	183,209	241,370
Total	$477,298	$937,331	$2,221,847	$3,636,476

(a)Represents our asset retirement obligation on an undiscounted basis. On a discounted basis the liability is $507 million as of December 31,

2023 as presented in the Consolidated Statement of Financial Position.

(b)Represents accrued expenses and net revenue clearing. Excludes taxes payable, asset retirement obligations and revenue to be distributed.

Refer to Note 23 in the Notes to the Group Financial Statements for information.

(c)Represents reserved capacity to transport gas from production locations through pipelines to the ultimate sales meters.

We believe that our cash flows from operations and existing liquidity will be sufficient to meet our existing contractual

obligations and commitments for the next twelve months, even under a stressed scenario as evidenced by our Viability and

Going Concern assessment. Cash flows from operations were $410 million for the year ended December 31, 2023, which

includes partial-year contributions from our Tanos II acquisition in 2023. Cash flows from operations were $388 million for the

year ended December 31, 2022, which similarly includes only a partial-year of contributions from our Central Region

acquisitions in 2022. As of December 31, 2023 and 2022, we had current assets of $305 million and $354 million, respectively,

and available borrowings on our Credit Facility of $146 million and $194 million, respectively, (excluding $11 million in

outstanding letters of credit, respectively), which could also be used to service our contractual obligations and commitments

over the next twelve months.

Litigation and Regulatory Proceedings

From time to time, we may be involved in legal proceedings in the ordinary course of business. We are not currently a party to

any material litigation proceedings, the outcome of which, if determined adversely to us, individually or in the aggregate, is

reasonably expected to have a material and adverse effect on our business, financial position or results of operations. In

addition, we are not aware of any material legal or administrative proceedings contemplated to be brought against us.

We have no other contingent liabilities that would have a material impact on our financial position, results of operations or

cash flows.

Environmental Matters

Our operations are subject to environmental laws and regulation in all the jurisdictions in which we operate. We are unable to

predict the effect of additional environmental laws and regulations that may be adopted in the future, including whether any

such laws or regulations would adversely affect our operations. We can offer no assurance regarding the significance or cost

of compliance associated with any such new environmental legislation or regulation once implemented.

In May 2022, we joined the Oil and Gas Methane Partnership 2.0 (the “OGMP”), a multi-stakeholder initiative launched by the

United Nations Environment Program and Climate and Clean Air Coalition in partnership with the European Commission, the

UK Government, Environmental Defense Fund and other leading natural gas and oil companies, to further advance our

commitment to reducing emissions.

The OGMP is a voluntary commitment which includes establishment of a credible pathway to attaining the “Gold Standard

Compliance” designation for the natural gas produced by the Group. We have attained the “Gold Standard Pathway” for our

implementation plan whereby we seek to improve our current measurement processes for natural gas emissions. We expect

the impact on our operations to be improved efficiency and reduced emissions.

RECENTLY ISSUED ACCOUNTING PRONOUNCEMENTS

Refer to Note 3 in the Notes to the Group Financial Statements for information regarding recent accounting pronouncements

applicable to our Consolidated Financial Statements.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	89

CRITICAL ACCOUNTING POLICIES AND ESTIMATES

Refer to Note 3 and 4 in the Notes to the Group Financial Statements for information regarding our significant accounting

policies, judgments and estimates.

QUANTITATIVE AND QUALITATIVE DISCLOSURE ABOUT MARKET RISK

Refer to Note 25 in the Notes to the Group Financial Statements for information regarding market risk.

TREND INFORMATION

Other than as disclosed elsewhere in this Annual Report & Form 20-F, we are not aware of any trends, uncertainties, demands,

commitments or events since December 31, 2023 that are reasonably likely to have a material adverse effect on our revenues,

income, profitability, liquidity or capital resources, or that would cause the disclosed financial information to be not necessarily

indicative of future operating results or financial conditions. For a discussion of trend information, Refer to Financial Review for

additional information.

90	Diversified Energy Company PLC Annual Report and Form 20-F2023

Risk Management Framework

Our ERM program focuses on the importance of

risk awareness and mitigation across the

organization. We proactively identify, assess,

prioritize, monitor and mitigate risks enabling

us to deliver the value-creating strategic

objectives outlined in our business model. The

Board regularly assesses our principal and

emerging risks.

ENTERPRISE RISK<br><br>MANAGEMENT PROGRAM<br><br>(Oversight and approval by the Audit & Risk Committee)

RISK UNIVERSE<br><br>Categories of risk
	STRATEGIC<br><br>RISKS	LEGAL,<br><br>REGULATORY<br><br>& REPUTATIONAL<br><br>RISKS
	OPERATIONAL<br><br>RISKS	FINANCIAL<br><br>RISKS

ENTERPRISE RISK<br><br>ASSESSMENT REVIEW<br><br>(Senior Management Team led with<br><br>business unit leader support)

PRINCIPAL RISKS
—Corporate Strategy<br><br>and Acquisition Risk<br><br>—Cybersecurity Risk<br><br>—Health and Safety Risk<br><br>—Regulatory and<br><br>Political Risk	—Climate Risk<br><br>—Commodity Price<br><br>Volatility Risk<br><br>—Financial Strength<br><br>and Flexibility Risk

ERM Program

Our ERM program is based on risk identification,

assessment, prioritization, monitoring and mitigation

processes, which are continually evaluated and enhanced

with experience and industry best practices.

As part of our ERM activities our Senior Leadership Team,

as directed by the Audit & Risk Committee of the Board,

regularly engages in risk discussions across all areas of our

operations. This healthy dialogue regarding risk creates a

culture that highly regards risk mitigation as a way to

preserve and create value for our stakeholders.

Within the program’s risk identification phase, we capture

potential and emerging risks that could arise as a result of a

change in circumstances or new developments impacting

us. To strengthen our risk identification, we carry out the

following ongoing activities:

—Continuous monitoring of the risk universe for new or

emerging risks;

—Refresh the risk universe at least annually;

—Enhance our risk awareness culture and identify

risk ownership;

—Interview risk owners for current mitigation

activities; and

—Design and implement a risk mitigation

control framework.

2023 and Ongoing

Risk Assessment

As part of our continuous assessment process during 2023,

each business unit head determined the perceived level of

risk for their individual unit’s risk universe. Our Senior

Leadership Team then reviewed and challenged each

perceived risk level, and compared it to our risk universe as

a whole. The results of this exercise were then used to

narrow our risk universe into four principal risk categories

and seven principal risks outlined below, which are closely

monitored by our Senior Leadership Team and the Audit &

Risk Committee.

During 2024, we will be updating our original risk

identification and mitigation assessment by conducting in-

depth interviews and group discussions with business

process owners to determine emerging and escalating risks

within the business and current business and market

environments. Based on the findings of the updated

assessment, we will reassess a new list of principal risks and

the resulting mitigation plans for each risk.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	91
Strategic Risks
---

Corporate Strategy and Acquisition Risk

Our future growth hinges on the successful completion of

acquisitions aligned with our strategic objectives. The

execution and seamless integration of these acquisitions

could exert substantial pressure on our managerial,

operational, and financial resources. Failure to adequately

assess, execute, and integrate these acquisitions may

adversely impact our business operations, financial

performance, and overall prospects.

Risk Indicators

The following KPIs are sensitive to the impact of Corporate

Strategy and Acquisition Risk:

—Adjusted operating cost per Mcfe

—Net cash provided by operating activities

—Maintain net debt-to-adjusted EBITDA at or below 2.5x

—Consistent adjusted EBITDA margin

Link to Strategy

—Acquire long-life stable assets

—Operate our assets in a safe, efficient and

responsible manner

—Generate reliable free cash flow

—Retire assets safely and responsibly and restore the

environment to its natural state

Response/Mitigation

—Disciplined commitment to our core strategy of

acquiring low-cost, long-life, relatively low-decline

producing assets and complementary, synergistic

midstream assets.

—Commercial Development, Land, Reserves, Strategic

Planning and Financial Planning & Analysis teams work

closely to identify and review potential acquisition

opportunities which meet strategic objective criteria.

—Experience and knowledge throughout the organization

in recognizing prospective opportunities.

—Thorough risk assessments and due diligence process on

all potential new acquisitions which includes an analysis

of the target’s emissions profile.

—Feedback and evaluation of external experts in the

diligence process.

—Strong balance sheet with significant liquidity to fund

growth through acquisitions.

Climate Risk

Climate-related matters remain central to numerous global

corporate discussions and decisions. While opportunities

related to climate continue to arise in this swiftly changing

landscape, we acknowledge that these issues also pose risks

for DEC. Environmental regulations, climate change concerns,

and investor-driven changes may lead to (i) increased

business costs, (ii) challenges in executing our strategy, and

(iii) restricted access to specific markets or investors.

Risk Indicators

The following KPIs are sensitive to the impact of

Climate Risk:

—Emissions intensity

—Maintain net debt-to-adjusted EBITDA at or below 2.5x

—Adjusted operating cost per Mcfe

—Net cash provided by operating activities

—Consistent adjusted EBITDA margin

—Meet or exceed state asset retirement goals

Link to Strategy

—Operate our assets in a safe, efficient and

responsible manner

—Retire assets safely and responsibly and restore the

environment to its natural state

Response/Mitigation

—Our Board oversees the development of our climate

change strategy which aims to position us at the heart of

the energy transition based on responsible stewardship

of existing natural gas assets. The Board’s decision-

making is informed by regular climate subject matter

updates from each of our key Board committees.

—Through our annual TCFD reporting process, we identify

and assess climate-related risks for consideration of

appropriate risk mitigation actions.

—Our core business strategy aligns with sustainability

initiatives and breeds sustainability. We acquire reliable,

long-life, producing wells that often have not reached

their full potential under their former owners. This

stewardship model allows us to avoid the high cost and

sometimes sizeable environmental impact often

associated with exploration and drilling, which is the

intended target of many sustainability initiatives.

—Alongside our zero-tolerance policy for fugitive

emissions, we invest capital funds towards emission

reduction technologies and projects and regularly deploy

SAM optimization techniques that allow us to eliminate

or reduce our carbon footprint.

—Our core KPI of methane intensity reduction is central to

our corporate goals to reduce both methane and GHG

emissions on our path towards net zero Scope 1 and 2

GHG emissions by 2040.

—We expanded our asset retirement capabilities, managed

through our Next LVL subsidiary, that will permit DEC to

exceed our long-term Appalachian asset retirement

agreements, reflective of our core KPI to Meet or exceed

state asset retirement goals.

92	Diversified Energy Company PLC Annual Report and Form 20-F2023
Financial Risks
---

Commodity Price Volatility Risk

Changes in commodity prices may affect the value of our

natural gas and oil reserves, operating cash flows and

adjusted EBITDA, regardless of our operating performance.

Risk Indicators

The following KPIs are sensitive to the impact of

Commodity Price Volatility Risk:

—Maintain net debt-to-adjusted EBITDA at or below 2.5x

—Consistent adjusted EBITDA margin

—Net cash provided by operating activities

Link to Strategy

—Generate reliable free cash flow

Response/Mitigation

—Our Senior Leadership Team monitors commodity

markets on a daily basis and internal models are

routinely updated to evaluate market changes. This

monitoring process includes reviewing realized pricing,

forward pricing curves, and basis differentials. This active

monitoring is critical to risk mitigation and the successful

execution of our hedge strategy.

—Our hedging policy continues to be guided by our goal

to generate reliable free cash flow in any commodity

pricing environment and secure our debt and dividend

payments. Our hedge strategy of proactively layering on

appropriately structured hedge contracts at

advantageous prices and tenors allows us to capitalize

on beneficial price movements in a constantly changing,

forward natural gas price market.

—External specialists are consulted on a regular basis to

assist in the execution of our hedging strategy.

Financial Strength and Flexibility Risk

Liquidity and access to capital risk arises from our inability

to generate cash flows from operations to fund our

business requirements or our inability to access external

sources of funding. This risk can result in difficulty in

meeting our financial obligations as they become due.

Risk Indicators

The following KPIs are sensitive to the impact of Financial

Strength and Flexibility Risk:

—Maintain net debt-to-adjusted EBITDA at or below 2.5x

—Consistent adjusted EBITDA margin

—Net cash provided by operating activities

—Meet or exceed state asset retirement goals

Link to Strategy

—Acquire long-life stable assets

—Operate our assets in a safe, efficient and

responsible manner

—Generate reliable free cash flow

—Retire assets safely and responsibly and restore the

environment to its natural state

Response/Mitigation

—Our Senior Leadership Team actively monitors debt

levels and available borrowing capacity on our

Credit Facility.

—Our Senior Leadership Team updates the Board at least

quarterly on our debt and liquidity position.

—Our business model of stable production contributes to

predictable cash flows, which makes it easier to forecast

funding needs.

—Strong access to bank capital as our borrowing base in

the Fall 2023 redetermination was reaffirmed

unanimously by our 14-bank group syndicate.

—Maintain access to multiple avenues of funding beyond

our Credit Facility: equity issuance, asset-backed

securitizations, and bond issuance.

—Proactive hedge program to protect against commodity

price volatility and stabilize operating cash flows.

—Continuous management review of the funding and

financing alternatives available to us to ensure sufficient

access to capital is available to meet our future needs.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	93
Legal, Regulatory and Reputational Risks
---

Regulatory and Political Risk

Our operations are subject to regulations in all the

jurisdictions in which we operate. We are unable to predict

the effect of additional laws and or regulations which may

be adopted in the future, including whether any such laws

or regulations would adversely affect our operations. We

can provide no assurance that such new legislation, once

implemented, will not oblige us to incur significant

expenses, undertake significant investments, or

reduce production.

Risk Indicators

The following KPIs are sensitive to the impact of Regulatory

and Political Risk:

—Maintain net debt-to-adjusted EBITDA at or below 2.5x

—Adjusted operating cost per Mcfe

—Net cash provided by operating activities

—Consistent adjusted EBITDA margin

—Emissions intensity

—Meet or exceed state asset retirement goals

—Safety Performance

Link to Strategy

—Operate our assets in a safe, efficient and

responsible manner

—Retire assets safely and responsibly and restore the

environment to its natural state

Response/Mitigation

—Operate to the highest industry standards with

regulators and monitor compliance with our contracts,

asset retirement program and taxation requirements.

—External specialists utilized on legal, regulatory, and tax

issues as required.

—Maintain positive relationships with governments and

key stakeholders.

—Continuous monitoring of the political and regulatory

environments in which we operate.

—Working responsibly and community/stakeholder

engagement and outreach is an important factor in

maintaining positive relationships in the communities in

which we operate.

—We encourage our employees to become actively

involved in their communities through industry

associations in their respective operating areas. By

leading, participating in and championing a variety of

these organizations, we believe that our support of the

energy industry’s associations adds value to our business

through the sharing of operating best practices,

technical knowledge and legislation updates, ultimately

to the benefit of all of our stakeholders.

Health and Safety Risk

Potential impacts from a lack of adherence to health and

safety policies may result in fines and penalties, serious

injury or death, environmental impacts, statutory liability for

environmental redemption and other financial and

reputational consequences that could be significant.

Risk Indicators

The following KPIs are sensitive to the impact of Health and

Safety Risk:

—Maintain net debt-to-adjusted EBITDA at or below 2.5x

—Adjusted operating cost per Mcfe

—Net cash provided by operating activities

—Consistent adjusted EBITDA margin

—Safety Performance

Link to Strategy

—Operate our assets in a safe, efficient and

responsible manner

—Retire assets safely and responsibly and restore the

environment to its natural state

Response/Mitigation

—Effectively managing Health and Safety Risk exposure is

the first priority for the Board and Senior Leadership

Team. The Safety & Sustainability Committee of the

Board regularly reviews health and safety programs

and mitigations.

—Health and safety training is included as part of all staff

and contractor inductions.

—Detailed training on our field manual procedures has

been provided to key stakeholders to ensure processes

and procedures are embedded throughout the

organization and all operations.

—Establishing processes for continually assessing our

overall operating and EHS capabilities, including

evaluations to determine the level of oversight required.

—Effective execution of the field operating manual

in operations.

—Crisis and emergency response procedures and

equipment are maintained and regularly tested to ensure

we are able to respond to an emergency quickly, safely

and effectively.

—Leading and lagging indicators and targets developed in

line with industry guidelines and benchmarks.

—Findings from ‘lessons learned’ reviews are implemented

on future operations.

—All employees maintain work stoppage ability.

94	Diversified Energy Company PLC Annual Report and Form 20-F2023
Operational Risk
---

Cybersecurity Risk

Cybersecurity risks for companies have increased

significantly in recent years due to the mounting threat and

increased sophistication of cybercrime. A cybersecurity

breach, incident or failure of our IT systems could disrupt

our businesses, put employees at risk, result in the

disclosure of confidential information, damage our

reputation and create significant financial and legal

exposure for DEC.

Our network is designed using a Zero Trust Approach

(“ZTA”) and is segmented. We’ve established several layers

of security, including least privilege access, conditional

access policies, and multi-factor authentication (“MFA”).

Our ZTA extends beyond our network to encompass

identity, endpoints, infrastructure, data, and applications.

This integrated ecosystem enables enhanced visibility,

intelligence, and automation for our security team. Due to

our 100% cloud environment, we now focus on continuous

testing of our security posture from both trusted and

untrusted sources—both external and internal to our

networks—rather than relying on a one-time penetration

testing approach. Additionally, we collaborate with a third-

party managed security service provider and utilize internal

resources for round-the-clock incident monitoring.

Risk Indicators

The following KPIs are sensitive to the impact of

Cybersecurity Risk:

—Maintain net debt-to-adjusted EBITDA at or below 2.5x

—Consistent adjusted EBITDA margin

—Net cash provided by operating activities

Link to Strategy

—Operate our assets in a safe, efficient and

responsible manner

—Generate reliable free cash flow

Response/Mitigation

—Employees are our first line of defense against these

attacks and we promote secure behaviors to help

mitigate this growing risk. We focus on practical rules

that we promote through robust mandatory annual

training and e-learning sessions delivered by our digital

security team. One of these rules addresses phishing and

reminds staff to ‘think before they click’.

—We engage with key technology partners and suppliers

to ensure potentially vulnerable systems are identified

and secured.

—We test our cybersecurity crisis management and

business continuity plans, recognizing the evolving

nature and pace of the threat landscape.

—Continuous implementation and monitoring of our IT

Security Policy, which includes measures to protect

against cyberattacks.

—Advanced network security detection which includes

regular threat testing.

—Control and protection of confidential information.

—Our Cybersecurity Council, which includes certain

members of the Senior Leadership Team including the

Chief Financial Officer, Chief Information Officer, Chief

Information Security Officer and General Counsel, meets

at least once a quarter to discuss cybersecurity issues,

risks and strategies. The Cybersecurity Council regularly

briefs (at least on a quarterly basis) the Board of

Directors on information security matters, including

assessing risks, efforts to improve our network security

systems and enhanced employee trainings. The

membership of this committee is adequately trained and

educated to provide proper governance, risk

management and control of the cyber security program

utilizing the National Institute of Standards and

Technology framework.

There were no cybersecurity incidents during the year

ended December 31, 2023, that resulted in an interruption

to our operations, known losses of any critical data or

otherwise had a material impact on the Group’s strategy,

financial condition or results of operations. However, the

scope and impact of any future incident cannot be

predicted. Refer to Risk Factors for more information

on how material cybersecurity attacks may impact

our business.

Our ERM program is based on<br><br>risk identification, assessment,<br><br>prioritization, monitoring and<br><br>mitigation processes, which are<br><br>continually evaluated and<br><br>enhanced with experience and<br><br>industry best practices.
Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	95
---	---	---	---	---

Risk Factors

You should carefully consider the risks described below, together with all of the other information in

this Annual Report & Form 20-F. The risks and uncertainties below are not the only ones we face.

Additional risks and uncertainties not presently known to us or that we believe to be immaterial may

also adversely affect our business. If any of the following risks occur, our business, financial condition,

and results of operations could be seriously harmed and you could lose all or part of your investment.

This Annual Report & Form 20-F also contains forward-looking statements that involve risks and

uncertainties. Our actual results may differ materially from those anticipated in these forward-looking

statements as a result of various factors, including the risks described below and elsewhere in this

Annual Report & Form 20-F.

Summary of Risk Factors

We are subject to a variety of risks and uncertainties which

could have a material adverse effect on our business,

financial condition, and results of operations. The summary

below is not exhaustive and is qualified by reference to the

full set of risk factors set forth in this “Risk Factors” section.

—Volatility and future decreases in natural gas, NGLs and

oil prices could materially and adversely affect our

business, results of operations, financial condition, cash

flows or prospects.

—We face production risks and hazards that may affect

our ability to produce natural gas, NGLs and oil at

expected levels, quality and costs that may result in

additional liabilities to us.

—The levels of our natural gas and oil reserves and

resources, their quality and production volumes may be

lower than estimated or expected.

—The present value of future net cash flows from our

reserves, or PV-10, will not necessarily be the same as the

current market value of our estimated natural gas, NGL

and oil reserves.

—We may face unanticipated increased or incremental

costs in connection with decommissioning obligations

such as plugging.

—We may not be able to keep pace with technological

developments in our industry or be able to implement

them effectively.

—Deterioration in the economic conditions in any of the

industries in which our customers operate, a domestic or

worldwide financial downturn, or negative credit market

conditions could have a material adverse effect on our

liquidity, results of operations, business and financial

condition that we cannot predict.

—Our operations are subject to a series of risks relating to

climate change.

—We rely on third-party infrastructure such as TC Energy

(formerly TransCanada), Enbridge, CNX, Dominion

Energy Transmission, Enlink, Williams and MarkWest

(defined herein) that we do not control and/or, in each

case, are subject to tariff charges that we do not control.

—Failure by us, our contractors or our primary offtakers to

obtain access to necessary equipment and

transportation systems could materially and adversely

affect our business, results of operations, financial

condition, cash flows or prospects.

—A proportion of our equipment has substantial prior use

and significant expenditure may be required to maintain

operability and operations integrity.

—We depend on our directors, key members of

management, independent experts, technical and

operational service providers and on our ability to retain

and hire such persons to effectively manage our

growing business.

—We may face unanticipated water and other waste

disposal costs.

—We may incur significant costs and liabilities resulting

from performance of pipeline integrity programs and

related repairs.

—Inflation may adversely affect us by increasing costs

beyond what we can recover through price increases

and limit our ability to enter into future debt financing.

—There are risks inherent in our acquisitions of natural gas

and oil assets.

—We may not have good title to all our assets

and licenses.

—Restrictions in our existing and future debt agreements

could limit our growth and our ability to engage in

certain activities.

—The securitizations of our limited purpose, bankruptcy-

remote, wholly owned subsidiaries may expose us to

financing and other risks, and there can be no assurance

that we will be able to access the securitization market in

the future, which may require us to seek more

costly financing.

96	Diversified Energy Company PLC Annual Report and Form 20-F2023

—We are subject to regulation and liability under

environmental, health and safety regulations, the

violation of which may affect our financial condition

and operations.

—Our operations are dependent on our compliance with

obligations under permits, licenses, contracts and field

development plans.

—Our operations are subject to the risk of litigation.

—The price of our ordinary shares may be volatile and may

fluctuate due to factors beyond our control.

—The dual listing of our ordinary shares may adversely

affect the liquidity and value of our ordinary shares.

—Failure to comply with requirements to design,

implement and maintain effective internal control over

financial reporting could have a material adverse effect

on our business.

—We are subject to certain tax risks, including changes in

tax legislation in the United Kingdom and the

United States.

Risks Related to Our Business, Operations and Industry

Volatility and future decreases in natural gas, NGLs and oil

prices could materially and adversely affect our business,

results of operations, financial condition, cash flows

or prospects.

Our business, results of operations, financial condition, cash

flows or prospects depend substantially upon prevailing

natural gas, NGL and oil prices, which may be adversely

impacted by unfavorable global, regional and national

macroeconomic conditions, including but not limited to

instability related to the military conflict in Ukraine. Natural

gas, NGLs and oil are commodities for which prices are

determined based on global and regional demand, supply

and other factors, all of which are beyond our control.

Historically, prices for natural gas, NGLs and oil have

fluctuated widely for many reasons, including:

—global and regional supply and demand, and

expectations regarding future supply and demand, for

gas and oil products;

—global and regional economic conditions;

—evolution of stocks of oil and related products;

—increased production due to new extraction

developments and improved extraction and

production methods;

—geopolitical uncertainty;

—threats or acts of terrorism, war or threat of war, which

may affect supply, transportation or demand;

—weather conditions, natural disasters, climate change and

environmental incidents;

—access to pipelines, storage platforms, shipping vessels

and other means of transporting, storing and refining gas

and oil, including without limitation, changes in

availability of, and access to, pipeline ullage;

—prices and availability of alternative fuels;

—prices and availability of new technologies affecting

energy consumption;

—increasing competition from alternative energy sources;

—the ability of OPEC and other oil-producing nations, to

set and maintain specified levels of production

and prices;

—political, economic and military developments in gas and

oil producing regions generally;

—governmental regulations and actions, including the

imposition of export restrictions and taxes and

environmental requirements and restrictions as well as

anti-hydrocarbon production policies;

—trading activities by market participants and others

either seeking to secure access to natural gas, NGLs and

oil or to hedge against commercial risks, or as part of an

investment portfolio; and

—market uncertainty, including fluctuations in currency

exchange rates, and speculative activities by those who

buy and sell natural gas, NGLs and oil on the

world markets.

It is impossible to accurately predict future gas, NGL and oil

price movements. Historically, natural gas prices have been

highly volatile and subject to large fluctuations in response

to relatively minor changes in the demand for natural gas.

According to the U.S. Energy Information Administration,

the historical high and low Henry Hub natural gas spot

prices per MMBtu for the following periods were as follows:

in 2021, high of $23.86 and low of $2.43; in 2022, high of

$9.85 and low of $3.46, and in 2023, high of $3.78 and low

of $1.74 — highlighting the volatile nature of

commodity prices.

The economics of producing from some wells and assets

may also result in a reduction in the volumes of our reserves

which can be produced commercially, resulting in

decreases to our reported reserves. Additionally, further

reductions in commodity prices may result in a reduction in

the volumes of our reserves. We might also elect not to

continue production from certain wells at lower prices, or

our license partners may not want to continue production

regardless of our position.

Each of these factors could result in a material decrease in

the value of our reserves, which could lead to a reduction in

our natural gas, NGLs and oil development activities and

acquisition of additional reserves. In addition, certain

development projects or potential future acquisitions could

become unprofitable as a result of a decline in price and

could result in us postponing or canceling a planned project

or potential acquisition, or if it is not possible to cancel, to

carry out the project or acquisition with negative economic

impacts. Further, a reduction in natural gas, NGL or oil

prices may lead our producing fields to be shut down and

to be entered into the decommissioning phase earlier

than estimated.

Our revenues, cash flows, operating results, profitability,

dividends, future rate of growth and the carrying value of

our gas and oil properties depend heavily on the prices we

receive for natural gas, NGLs and oil sales. Commodity

prices also affect our cash flows available for capital

investments and other items, including the amount and

value of our gas and oil reserves. In addition, we may face

gas and oil property impairments if prices fall significantly.

In light of the continuing increase in supply coming from the

Utica and Marcellus shale plays of the Appalachian Basin, no

assurance can be given that commodity prices will remain at

levels which enable us to do business profitably or at levels

that make it economically viable to produce from certain

wells and any material decline in such prices could result in

a reduction of our net production volumes and revenue and

a decrease in the valuation of our production properties,

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	97

which could negatively impact our business, results of

operations, financial condition, cash flows or prospects.

We conduct our business in a highly competitive industry.

The gas and oil industry is highly competitive. The key areas

in which we face competition include:

—engagement of third-party service providers whose

capacity to provide key services may be limited;

—acquisition of other companies that may already own

licenses or existing producing assets;

—acquisition of assets offered for sale by other companies;

—access to capital (debt and equity) for financing and

operational purposes;

—purchasing, leasing, hiring, chartering or other procuring

of equipment that may be scarce; and

—employment of qualified and experienced skilled

management and gas and oil professionals and field

operations personnel.

Competition in our markets is intense and depends, among

other things, on the number of competitors in the market,

their financial resources, their degree of geological,

geophysical, engineering and management expertise and

capabilities, their degree of vertical integration and pricing

policies, their ability to develop properties on time and on

budget, their ability to select, acquire and develop reserves

and their ability to foster and maintain relationships with

the relevant authorities. The cost to attract and retain

qualified and experienced personnel has increased and may

increase substantially in the future.

Our competitors also include those entities with greater

technical, physical and financial resources than us. Finally,

companies and certain private equity firms not previously

investing in natural gas and oil may choose to acquire

reserves to establish a firm supply or simply as an

investment. Any such companies will also increase market

competition which may directly affect us.

The effects of operating in a competitive industry

may include:

—higher than anticipated prices for the acquisition of

licenses or assets;

—the hiring by competitors of key management or other

personnel; and

—restrictions on the availability of equipment or services.

If we are unsuccessful in competing against other

companies, our business, results of operations, financial

condition, cash flows or prospects could be materially

adversely affected.

We may experience delays in production, transportation

and marketing.

Various production, transportation and marketing

conditions may cause delays in natural gas, NGLs and oil

production and adversely affect our business. For example,

the gas gathering systems that we own connect to other

pipelines or facilities which are owned and operated by

third parties. These pipelines and other midstream facilities

and others upon which we rely may become unavailable

because of testing, turnarounds, line repair, reduced

operating pressure, lack of operating capacity, regulatory

requirements, curtailments of receipt or deliveries due to

insufficient capacity or because of damage. In periods

where NGL prices are high, we benefit greatly from the

ability to process NGLs. Our largest processor of NGLs is

the MarkWest Energy Partners, L.P., (“MarkWest”) plant

located in Langley, Kentucky. If we were to lose the ability

to process NGLs at MarkWest’s plant during a period of

high pricing, our revenues would be negatively impacted.

As a short-term measure, we could divert the natural gas

through other pipeline routes; however, certain pipeline

operators would eventually decline to transport the gas due

to its liquid content at a level that would exceed tariff

specifications for those pipelines. The lack of available

capacity on third-party systems and facilities could reduce

the price offered for our production or result in the shut-in

of producing wells. Any significant changes affecting these

infrastructure systems and facilities, as well as any delays in

constructing new infrastructure systems and facilities, could

delay our production, which could negatively impact our

business, results of operations, financial condition, cash

flows or prospects.

We face production risks and hazards that may affect our

ability to produce natural gas, NGLs and oil at expected

levels, quality and costs that may result in additional

liabilities to us.

Our natural gas and oil production operations are subject to

numerous risks common to our industry, including, but not

limited to, premature decline of reservoirs, incorrect

production estimates, invasion of water into producing

formations, geological uncertainties such as unusual or

unexpected rock formations and abnormal geological

pressures, low permeability of reservoirs, contamination of

natural gas and oil, blowouts, oil and other chemical spills,

98	Diversified Energy Company PLC Annual Report and Form 20-F2023

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explosions, fires, equipment damage or failure, challenges

relating to transportation, pipeline infrastructure, natural

disasters, uncontrollable flows of oil, natural gas or well

fluids, adverse weather conditions, shortages of skilled

labor, delays in obtaining regulatory approvals or consents,

pollution and other environmental risks.

If any of the above events occur, environmental damage,

including biodiversity loss or habitat destruction, injury to

persons or property and other species and organisms, loss

of life, failure to produce natural gas, NGLs and oil in

commercial quantities or an inability to fully produce

discovered reserves could result. These events could also

cause substantial damage to our property or the property

of others and our reputation and put at risk some or all of

our interests in licenses, which enable us to produce, and

could result in the incurrence of fines or penalties, criminal

sanctions potentially being enforced against us and our

management, as well as other governmental and third-party

claims. Consequent production delays and declines from

normal field operating conditions and other adverse actions

taken by third parties may result in revenue and cash flow

levels being adversely affected.

Moreover, should any of these risks materialize, we could

incur legal defense costs, remedial costs and substantial

losses, including those due to injury or loss of life, human

health risks, severe damage to or destruction of property,

natural resources and equipment, environmental damage,

unplanned production outages, clean-up responsibilities,

regulatory investigations and penalties, increased public

interest in our operational performance and suspension of

operations, which could negatively impact our business,

results of operations, financial condition, cash flows

or prospects.

The levels of our natural gas and oil reserves and

resources, their quality and production volumes may be

lower than estimated or expected.

The reserves data as of December 31, 2023, 2022 and 2021

contained in this Annual Report & Form 20-F has been

audited by NSAI unless stated otherwise. The standards

utilized to prepare the reserves information that has been

extracted in this document may be different from the

standards of reporting adopted in other jurisdictions.

Investors, therefore, should not assume that the data found

in the reserves information set forth in this Annual Report &

Form 20-F is directly comparable to similar information that

has been prepared in accordance with the reserve reporting

standards of other jurisdictions, such as the United

Kingdom.

In general, estimates of economically recoverable natural

gas, NGLs and oil reserves are based on a number of factors

and assumptions made as of the date on which the reserves

estimates were determined, such as geological, geophysical

and engineering estimates (which have inherent

uncertainties), historical production from the properties or

analogous reserves, the assumed effects of regulation by

governmental agencies and estimates of future commodity

prices, operating costs, gathering and transportation costs

and production related taxes, all of which may vary

considerably from actual results.

Underground accumulations of hydrocarbons cannot be

measured in an exact manner and estimates thereof are a

subjective process aimed at understanding the statistical

probabilities of recovery. Estimates of the quantity of

economically recoverable natural gas and oil reserves, rates

of production and, where applicable, the timing of

development expenditures depend upon several variables

and assumptions, including the following:

—production history compared with production from other

comparable producing areas;

—quality and quantity of available data;

—interpretation of the available geological and

geophysical data;

—effects of regulations adopted by

governmental agencies;

—future percentages of sales;

—future natural gas, NGLs and oil prices;

—capital investments;

—effectiveness of the applied technologies and equipment;

—effectiveness of our field operations employees to

extract the reserves;

—natural events or the negative impacts of

natural disasters;

—future operating costs, tax on the extraction of

commercial minerals, development costs and workover

and remedial costs; and

—the judgment of the persons preparing the estimate.

As all reserve estimates are subjective, each of the

following items may differ materially from those assumed in

estimating reserves:

—the quantities and qualities that are ultimately recovered;

—the timing of the recovery of natural gas and oil reserves;

—the production and operating costs incurred;

—the amount and timing of development expenditures, to

the extent applicable;

—future hydrocarbon sales prices; and

—decommissioning costs and changes to regulatory

requirements for decommissioning.

Many of the factors in respect of which assumptions are

made when estimating reserves are beyond our control and

therefore these estimates may prove to be incorrect over

time. Evaluations of reserves necessarily involve multiple

uncertainties. The accuracy of any reserves evaluation

depends on the quality of available information and natural

gas, NGLs and oil engineering and geological interpretation.

Furthermore, less historical well production data is available

for unconventional wells because they have only become

technologically viable in the past twenty years and the

long-term production data is not always sufficient to

determine terminal decline rates. In comparison, some

conventional wells in our portfolio have been productive for

a much longer time. As a result, there is a risk that estimates

of our shale reserves are not as reliable as estimates of the

conventional well reserves that have a longer historical

profile to draw on. Interpretation, testing and production

after the date of the estimates may require substantial

upward or downward revisions in our reserves and

resources data. Moreover, different reserve engineers may

make different estimates of reserves and cash flows based

on the same available data. Actual production, revenues

and expenditures with respect to reserves will vary from

estimates and the variances may be material.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	99

If the assumptions upon which the estimates of our natural

gas and oil reserves prove to be incorrect or if the actual

reserves available to us (or the operator of an asset in we

have an interest) are otherwise less than the current

estimates or of lesser quality than expected, we may be

unable to recover and produce the estimated levels or

quality of natural gas, NGLs or oil set out in this document

and this may materially and adversely affect our business,

results of operations, financial condition, cash flows

or prospects.

The PV-10, will not necessarily be the same as the current

market value of our estimated natural gas, NGL and

oil reserves.

You should not assume that the present value of future net

cash flows from our reserves is the current market value of

our estimated natural gas, NGL and oil reserves. Actual

future net cash flows from our natural gas and oil properties

will be affected by factors such as:

—actual prices we receive for natural gas, NGL and oil;

—actual cost of development and

production expenditures;

—the amount and timing of actual production;

—transportation and processing; and

—changes in governmental regulations or taxation.

The timing of both our production and our incurrence of

expenses in connection with the development and

production of our natural gas and oil properties will affect

the timing and amount of actual future net cash flows from

reserves, and thus their actual present value. In addition, the

10% discount factor we use when calculating discounted

future net cash flows may not be the most appropriate

discount factor based on interest rates in effect from time

to time and risks associated with us or the natural gas and

oil industry in general. Actual future prices and costs may

differ materially from those used in the present value

estimate. Refer to the APMs section in Additional

Information within this Annual Report & Form 20-F for

additional information regarding our use of PV-10.

We may face unanticipated increased or incremental costs

in connection with decommissioning obligations such

as plugging.

In the future, we may become responsible for costs

associated with abandoning and reclaiming wells, facilities

and pipelines which we use for the processing of natural gas

and oil reserves. With regards to plugging, we are party to

agreements with regulators in the states of Ohio, West

Virginia, Kentucky and Pennsylvania, four of our largest

wellbore states, setting forth plugging and abandonment

schedules spanning a period ranging from 10 to 15 years. We

will incur such decommissioning costs at the end of the

operating life of some of our properties. The ultimate

decommissioning costs are uncertain and cost estimates can

vary in response to many factors including changes to

relevant legal requirements, the emergence of new

restoration techniques, the shortage of plugging vendors,

difficult terrain or weather conditions or experience at other

production sites. The expected timing and amount of

expenditure can also change, for example, in response to

changes in reserves, wells losing commercial viability sooner

than forecasted or changes in laws and regulations or their

interpretation. As a result, there could be significant

adjustments to the provisions established which would affect

future financial results. The use of other funds to satisfy such

decommissioning costs may impair our ability to focus

capital investment in other areas of our business, which

could materially and adversely affect our business, results of

operations, financial condition, cash flows or prospects.

We may not be able to keep pace with technological

developments in our industry or be able to implement

them effectively.

The natural gas and oil industry is characterized by rapid

and significant technological advancements and

introductions of new products and services using new

technologies, such as emissions controls and processing

technologies. Rapid technological advancements in

information technology and operational technology

domains require seamless integration. Failure to integrate

these technologies efficiently may result in operational

inefficiencies, security vulnerabilities, and increased costs.

During mergers and acquisitions, integrating technology

assets from acquired companies can be complex. Poor

integration may lead to data inconsistencies, security gaps

and operational disruptions. Technology systems are also

susceptible to cybersecurity threats, including malware,

data breaches, and ransomware attacks. These threats may

disrupt operations, compromise sensitive data and lead to

significant financial losses. Further, inefficient data

management practices may result in data breaches, data

loss and missed opportunities for operational insights. The

presence of legacy technology systems can also pose

challenges, as they may lack modern security features,

making them vulnerable to cyber threats and necessitating

costly upgrades. As others use or develop new

technologies, we may be placed at a competitive

disadvantage or may be forced by competitive pressures to

implement those new technologies at substantial costs. In

addition, other natural gas and oil companies may have

greater financial, technical and personnel resources that

allow them to enjoy technological advantages, which may

in the future allow them to implement new technologies

before we can. Additionally, reliance on global supply

chains for information technology hardware, software and

operational technology equipment exposes the industry to

supply chain disruptions, shortages and cybersecurity risks.

A lowering or withdrawal of the ratings, outlook or watch

assigned to us or our debt by rating agencies may increase

our future borrowing costs and reduce our access to capital.

The rating, outlook or watch assigned to us or our debt

could be lowered or withdrawn entirely by a rating agency

if, in that rating agency’s judgment, current or future

circumstances relating to the basis of the rating, outlook, or

watch such as adverse changes to our business, so warrant.

Our credit ratings may also change as a result of the

differing methodologies or changes in the methodologies

used by the rating agencies. Any future lowering of our

debt’s ratings, outlook or watch likely would make it more

difficult or more expensive for us to obtain additional

debt financing.

It is also possible that such ratings may be lowered in

connection with this listing or in connection with future

events, such as future acquisitions. Holders of our ordinary

shares will have no recourse against us or any other parties

in the event of a change in or suspension or withdrawal of

such ratings. Any lowering, suspension or withdrawal of

such ratings may have an adverse effect on the market

price or marketability of our ordinary shares.

100	Diversified Energy Company PLC Annual Report and Form 20-F2023

If we do not have access to capital on favorable terms, on

the timeline we require, or at all, our financial condition

and results of operations could be materially

adversely affected.

We require capital to complete acquisitions that we believe

will enhance shareholder return. Significant volatility or

disruption in the global financial markets may result in us not

being able to obtain additional financing on favorable terms,

on the timeline we anticipate, or at all, and we may not be

able to refinance, if necessary, any outstanding debt when

due, all of which could have a material adverse effect on our

financial condition. Any inability to obtain additional funding

on favorable terms, on the timeline we anticipate, or at all,

may prevent us from acquiring new assets, cause us to

curtail our operations significantly, reduce planned capital

expenditures or obtain funds through arrangements that

management does not currently anticipate, including

disposing of our assets, the occurrence of any of which may

significantly impair our ability to deliver shareholder returns.

If our operating results falter, our cash flow or capital

resources prove inadequate, or if interest rates increase

significantly, we could face liquidity problems that could

materially and adversely affect our results of operations and

financial condition.

Deterioration in the economic conditions in any of the

industries in which our customers operate, a domestic or

worldwide financial downturn, or negative credit market

conditions could have a material adverse effect on our

liquidity, results of operations, business and financial

condition that we cannot predict.

Economic conditions in a number of industries in which our

customers operate have experienced substantial

deterioration in the past, resulting in reduced demand for

natural gas and oil. Renewed or continued weakness in the

economic conditions of any of the industries we serve or

that are served by our customers, or the increased focus by

markets on carbon-neutrality, could adversely affect our

business, financial condition, results of operation and

liquidity in a number of ways. For example:

—demand for natural gas and electricity in the United

States is impacted by industrial production, which if

weakened would negatively impact the revenues,

margins and profitability of our natural gas business;

—a decrease in international demand for natural gas or

NGLs produced in the United States could adversely

affect the pricing for such products, which could

adversely affect our results of operations and liquidity;

—the tightening of credit or lack of credit availability to

our customers could adversely affect our liquidity, as our

ability to receive payment for our products sold and

delivered depends on the continued creditworthiness of

our customers;

—our ability to refinance our Credit Facility may be limited

and the terms on which we are able to do so may be less

favorable to us depending on the strength of the capital

markets or our credit ratings;

—our ability to access the capital markets may be

restricted at a time when we would like, or need, to raise

capital for our business including for exploration and/or

development of our natural gas reserves;

—increased capital markets scrutiny of oil and gas

companies may lead to increased costs of capital or lack

of credit availability; and

—a decline in our creditworthiness may require us to post

letters of credit, cash collateral, or surety bonds to

secure certain obligations, all of which would have an

adverse effect on our liquidity.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	101

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Our operations are subject to a series of risks relating to

climate change.

Continued public concern regarding climate change and

potential mitigation through regulation could have a

material impact on our business. International agreements,

national, regional, state and local legislation, and regulatory

measures to limit GHG emissions are currently in place or in

various stages of discussion or implementation. For

example, the Inflation Reduction Act, which was signed into

law in August 2022, includes a “methane fee” that is

expected to be imposed beginning with emissions reported

for calendar year 2024. In addition, the current U.S.

administration has proposed more stringent methane

pollution limits for new and existing gas and oil operations.

Given that some of our operations are associated with

emissions of GHGs, these and other GHG emissions-related

laws, policies and regulations may result in substantial

capital, compliance, operating and maintenance costs. The

level of expenditure required to comply with these laws and

regulations is uncertain and is expected to vary depending

on the laws enacted by particular countries, states,

provinces and municipalities.

Additionally, regulatory, market and other changes to

respond to climate change may adversely impact our

business, financial condition or results of operations.

Reporting expectations are also increasing, with a variety of

customers, capital providers and regulators seeking

increased information on climate-related risks. For example,

the SEC has adopted climate-related disclosures rules that

may require us to incur significant costs to assess and

disclose on a range of climate-related data and risks.

Internationally, the United Nations-sponsored “Paris

Agreement” requires member nations to individually

determine and submit non-binding emissions reduction

targets every five years after 2020. President Biden has

recommitted the United States to the Paris Agreement and,

in April 2021, announced a goal of reducing the United

States’ emissions by 50-52% below 2005 levels by 2030. In

November 2021, the international community gathered in

Glasgow at the 26th Conference of the Parties to the UN

Framework Convention on Climate Change, during which

multiple announcements were made, including a call for

parties to eliminate certain fossil fuel subsidies and pursue

further action on non-carbon dioxide GHGs. Relatedly, the

United States and European Union jointly announced the

launch of the “Global Methane Pledge,” which aims to cut

global methane pollution at least 30% by 2030 relative to

2020 levels, including “all feasible reductions” in the energy

sector. Such commitments were re-affirmed at the 27th

Conference of the Parties in Sharm El Sheikh. The emission

reduction targets and other provisions of legislative or

regulatory initiatives and policies enacted in the future by

the United States or states in which we operate, could

adversely impact our business by imposing increased costs

in the form of higher taxes or increases in the prices of

emission allowances, limiting our ability to develop new gas

and oil reserves, transport hydrocarbons through pipelines

or other methods to market, decreasing the value of our

assets, or reducing the demand for hydrocarbons and

refined petroleum products. With increased pressure to

reduce GHG emissions by replacing fossil fuel energy

generation with alternative energy generation, it is possible

that peak demand for gas and oil will be reached, and gas

and oil prices will be adversely impacted as and when this

happens. Further, the consequences of the effects of global

climate change, and the continued political and societal

attention afforded to mitigating the effects of climate

change, may generate adverse investor and stakeholder

sentiment towards the hydrocarbon industry and negatively

impact the ability to invest in the sector. Similarly, longer

term reduction in the demand for hydrocarbon products

due to the pace of commercial deployment of alternative

energy technologies or due to shifts in consumer

preference for lower GHG emissions products could reduce

the demand for the hydrocarbons that we produce.

Additionally, the SEC’s proposed climate rule published in

March 2022, requiring disclosure of a range of climate

related risks, is expected to be finalized late-2023. We are

currently assessing this rule, and at this time we cannot

predict the costs of implementation or any potential

adverse impacts resulting from the rule. To the extent this

rule is finalized as proposed, we or our customers could

incur increased costs related to the assessment and

disclosure of climate-related risks. Additionally, enhanced

climate disclosure requirements could accelerate the trend

of certain stakeholders and lenders restricting or seeking

more stringent conditions with respect to their investments

in certain carbon intensive sectors.

Further, in response to concerns related to climate change,

companies in the fossil fuel sector may be exposed to

increasing financial risks. Financial institutions, including

investment advisors and certain sovereign wealth, pension

and endowment funds, may elect in the future to shift some

or all of their investment into non-fossil fuel related sectors.

Institutional lenders who provide financing to fossil-fuel

energy companies have also become more attentive to

sustainable lending practices, and some of them may elect in

the future not to provide funding for fossil fuel energy

companies. There is also a risk that financial institutions will

be required to adopt policies that have the effect of

reducing the funding provided to the fossil fuel sector. In

2021, President Biden signed an executive order calling for

the development of a “climate finance plan,” and, separately,

the Federal Reserve announced in 2020 that it has joined the

Network for Greening the Financial System, a consortium of

financial regulators focused on addressing climate-related

risks in the financial sector. A material reduction in the

capital available to the fossil fuel industry could make it more

difficult to secure funding for exploration, development,

production, and transportation activities, which could in turn

negatively affect our operations.

The Group may also be subject to activism from

environmental non-governmental organizations (“NGOs”)

campaigning against fossil fuel extraction or negative

publicity from media alleging inadequate remedial actions to

retire non-producing wells effectively, which could affect our

reputation, disrupt our programs, require us to incur

significant, unplanned expense to respond or react to

intentionally disruptive campaigns or media reports, create

blockades to interfere with operations or otherwise

negatively impact our business, results of operations,

financial condition, cash flows or prospects. Litigation risks

are also increasing as a number of entities have sought to

bring suit against various oil and natural gas companies in

state or federal court, alleging among other things, that such

companies created public nuisances by producing fuels that

contributed to climate change or alleging that the companies

have been aware of the adverse effects of climate change for

some time but defrauded their investors or customers by

failing to adequately disclose those impacts.

102	Diversified Energy Company PLC Annual Report and Form 20-F2023

Finally, our operations are subject to disruption from the

physical effects that may be caused or aggravated by

climate change. These include risks from extreme weather

events, such as hurricanes, severe storms, floods, heat

waves, and ambient temperature increases, as well as

wildfires, each of which may become more frequent or

more severe as a result of climate change.

We rely on third-party infrastructure that we do not

control and/or, in each case, are subject to tariff charges

that we do not control.

A significant portion of our production passes through

third-party owned and controlled infrastructure. If these

third-party pipelines or liquids processing facilities

experience any event that causes an interruption in

operations or a shut-down such as mechanical problems, an

explosion, adverse weather conditions, a terrorist attack or

labor dispute, our ability to produce or transport natural gas

could be severely affected. For example, we have an

agreement with a third-party where approximately 49% of

the NGLs we sold during the year ending December 31, 2023

were processed at the third-party’s facility in Kentucky. Any

material decrease in our ability to process or transport our

natural gas through third-party infrastructure could have a

material adverse effect on our business, results of

operations, financial condition, cash flows or prospects.

Our use of third-party infrastructure may be subject to tariff

charges. Although we seek to manage our flow via our

midstream infrastructure, we may not always be able to

avoid higher tariffs or basis blowouts due to the lack of

interconnections. In such instances, the tariff charges can be

substantial and the cost is not subject to our direct control,

although we may have certain contractual or governmental

protections and rights. Generally, the operator of the

gathering or transmission pipelines sets these tariffs and

expenses on a cost sharing basis according to our

proportionate hydrocarbon through-put of that facility. A

provisional tariff rate is applied during the relevant year and

then finalized the following year based on the actual final

costs and final through-put volumes. Such tariffs are

dependent on continued production from assets owned by

third parties and, may be priced at such a level as to lead to

production from our assets ceasing to be economic and thus

may have a material adverse effect on our business, results

of operations, financial condition, cash flows or prospects.

Furthermore, our use of third-party infrastructure exposes

us to the possibility that such infrastructure will cease to be

operational or be decommissioned and therefore require us

to source alternative export routes and/or prevent

economic production from our assets. This could also have

a material adverse effect on our business, results of

operations, financial condition, cash flows or prospects.

Failure by us, our contractors or our primary offtakers to

obtain access to necessary equipment and transportation

systems could materially and adversely affect our

business, results of operations, financial condition, cash

flows or prospects.

We rely on our natural gas and oil field suppliers and

contractors to provide materials and services that facilitate

our production activities, including plugging and

abandonment contractors. Any competitive pressures on

the oil field suppliers and contractors could result in a

material increase of costs for the materials and services

required to conduct our business and operations. For

example, we are dependent on the availability of plugging

vendors to help us satisfy abandonment schedules that we

have agreed to with the states of Ohio, West Virginia,

Kentucky and Pennsylvania. Such personnel and services

can be scarce and may not be readily available at the times

and places required. Future cost increases could have a

material adverse effect on our asset retirement liability,

operating income, cash flows and borrowing capacity and

may require a reduction in the carrying value of our

properties, our planned level of spending for development

and the level of our reserves. Prices for the materials and

services we depend on to conduct our business may not be

sustained at levels that enable us to operate profitably.

We and our offtakers rely, and any future offtakers will rely,

upon the availability of pipeline and storage capacity

systems, including such infrastructure systems that are

owned and operated by third parties. As a result, we may

be unable to access or source alternatives for the

infrastructure and systems which we currently use or plan

to use, or otherwise be subject to interruptions or delays in

the availability of infrastructure and systems necessary for

the delivery of our natural gas, NGLs and oil to commercial

markets. In addition, such infrastructure may be close to its

design life and decisions may be taken to decommission

such infrastructure or perform life extension work to

maintain continued operations. Any of these events could

result in disruptions to our projects and thereby impact our

ability to deliver natural gas, NGLs and oil to commercial

markets and/or may increase our costs associated with the

production of natural gas, NGLs and oil reliant upon such

infrastructure and systems. Further, our offtakers could

become subject to increased tariffs imposed by

government regulators or the third-party operators or

owners of the transportation systems available for the

transport of our natural gas, NGLs and oil, which could

result in decreased offtaker demand and downward

pricing pressure.

If we are unable to access infrastructure systems facilitating

the delivery of our natural gas, NGLs and oil to commercial

markets due to our contractors or primary offtakers being

unable to access the necessary equipment or transportation

systems, our operations will be adversely affected. If we are

unable to source the most efficient and expedient

infrastructure systems for our assets then delivery of our

natural gas, NGLs and oil to the commercial markets may

be negatively impacted, as may our costs associated with

the production of natural gas, NGLs and oil reliant upon

such infrastructure and systems.

A proportion of our equipment has substantial prior use

and significant expenditure may be required to maintain

operability and operations integrity.

A part of our business strategy is to optimize or refurbish

producing assets where possible to maximize the efficiency

of our operations while avoiding significant expenses

associated with purchasing new equipment. Our producing

assets and midstream infrastructure require ongoing

maintenance to ensure continued operational integrity. For

example, some older wells may struggle to produce suitable

line pressure and will require the addition of compression to

push natural gas. Despite our planned operating and capital

expenditures, there can be no guarantee that our assets or

the assets we use will continue to operate without fault and

not suffer material damage in this period through, for

example, wear and tear, severe weather conditions, natural

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	103

disasters or industrial accidents. If our assets, or the assets

we use, do not operate at or above expected efficiencies,

we may be required to make substantial expenditures

beyond the amounts budgeted. Any material damage to

these assets or significant capital expenditure on these

assets for improvement or maintenance may have a

material adverse effect on our business, results of

operations, financial condition, cash flows or prospects. In

addition, as with planned operating and capital expenditure,

there is no guarantee that the amounts expended will

ensure continued operation without fault or address the

effects of wear and tear, severe weather conditions, natural

disasters or industrial accidents. We cannot guarantee that

such optimization or refurbishment will be commercially

feasible to undertake in the future and we cannot provide

assurance that we will not face unexpected costs during the

optimization or refurbishment process.

We depend on our directors, key members of

management, independent experts, technical and

operational service providers and on our ability to retain

and hire such persons to effectively manage our

growing business.

Our future operating results depend in significant part upon

the continued contribution of our directors, key senior

management and technical, financial and operations

personnel. Management of our growth will require, among

other things, stringent control of financial systems and

operations, the continued development of our control

environment, the ability to attract and retain sufficient

numbers of qualified management and other personnel, the

continued training of such personnel and the presence of

adequate supervision.

In addition, the personal connections and relationships of

our directors and key management are important to the

conduct of our business. If we were to unexpectedly lose a

member of our key management or fail to maintain one of

the strategic relationships of our key management team,

our business, results of operations, financial condition, cash

flows or prospects could be materially adversely affected.

In particular, we are highly dependent on our Chief

Executive Officer, Robert Russell (“Rusty”) Hutson, Jr.

Acquisitions are a key part of our strategy, and Mr. Hutson

has been instrumental in sourcing them and securing their

financing. Furthermore, as our founder, Mr. Hutson is

strongly associated with our success, and if he were to

cease being the Chief Executive Officer, perception of our

future prospects may be diminished. We maintain a “key

person” life insurance policy on Mr. Hutson, but not any

other of our employees. As a result, we are insured against

certain losses resulting from the death of Mr. Hutson, but

not any of our other employees.

Attracting and retaining additional skilled personnel will be

fundamental to the continued growth and operation of our

business. We require skilled personnel in the areas of

development, operations, engineering, business

development, natural gas, NGLs and oil marketing, finance

and accounting relating to our projects. Personnel costs,

including salaries, are increasing as industry wide demand

for suitably qualified personnel increases. We may not

successfully attract new personnel and retain existing

personnel required to continue to expand our business and

to successfully execute and implement our

business strategy.

We may face unanticipated water and other waste

disposal costs.

We may be subject to regulation that restricts our ability to

discharge water produced as part of our natural gas, oil and

NGL production operations. Productive zones frequently

contain water that must be removed for the natural gas, oil

and NGL to produce, and our ability to remove and dispose

of sufficient quantities of water from the various zones will

determine whether we can produce natural gas, oil and NGL

in commercial quantities. The produced water must be

transported from the leasehold and/or injected into

disposal wells. The availability of disposal wells with

sufficient capacity to receive all of the water produced from

our wells may affect our ability to produce our wells. Also,

the cost to transport and dispose of that water, including

the cost of complying with regulations concerning water

disposal, may reduce our profitability. We have entered into

various water management services agreements in the

Appalachian Basin which provide for the disposal of our

produced water by established counterparties with large

integrated pipeline networks. If these counterparties fail to

perform, we may have to shut in wells, reduce drilling

activities, or upgrade facilities for water handling or

treatment. The costs to dispose of this produced water may

increase for a number of reasons, including if new laws and

regulations require water to be disposed in a

different manner.

104	Diversified Energy Company PLC Annual Report and Form 20-F2023

img_Pikeville Selects-36.jpg

In 2016, the EPA adopted effluent limitations for the

treatment and discharge of wastewater resulting from

onshore unconventional natural gas, oil and NGL extraction

facilities to publicly owned treatment works. In addition, the

injection of fluids gathered from natural gas, oil and NGL

producing operations in underground disposal wells has

been identified by some groups and regulators as a

potential cause of increased seismic events in certain areas

of the country, including the states of West Virginia, Ohio

and Kentucky in the Appalachian Basin as well as

Oklahoma, Texas and Louisiana in our Central Region.

Certain states, including those located in the Appalachian

Basin have adopted, or are considering adopting, laws and

regulations that may restrict or prohibit oilfield fluid

disposal in certain areas or underground disposal wells, and

state agencies implementing those requirements may issue

orders directing certain wells in areas where seismic events

have occurred to restrict or suspend disposal well permits

or operations or impose certain conditions related to

disposal well construction, monitoring, or operations. Any

of these developments could increase our cost to dispose

of our produced water.

We may incur significant costs and liabilities resulting

from performance of pipeline integrity programs and

related repairs.

Pursuant to the authority under the Natural Gas Pipeline

Safety Act of 1968 (“NGPSA”) and Hazardous Liquid

Pipeline Safety Act of 1979 (“HLPSA”), as amended by the

Pipeline Safety Improvement Act of 2002 (“PSIA”), the

Pipeline Inspection, Protection, Enforcement and Safety Act

of 2006 (“PIPESA”) and the Pipeline Safety, Regulatory

Certainty, and Job Creation Act of 2011 (the “2011 Pipeline

Safety Act”), the Pipeline and Hazardous Materials Safety

Administration (“PHMSA”) has promulgated regulations

requiring pipeline operators to develop and implement

integrity management programs for certain gas and

hazardous liquid pipelines that, in the event of a pipeline

leak or rupture could affect high consequence areas

(“HCAs”), which are areas where a release could have the

most significant adverse consequences, including high-

population areas, certain drinking water sources and

unusually sensitive ecological areas. These regulations

require operators of covered pipelines to:

—perform ongoing assessments of pipeline integrity;

—identify and characterize applicable threats to pipeline

segments that could impact HCAs;

—improve data collection, integration and analysis;

—repair and remediate the pipeline as necessary; and

—implement preventive and mitigating actions.

In addition, states have adopted regulations similar to

existing PHMSA regulations for certain intrastate gas and

hazardous liquid pipelines. At this time, we cannot predict

the ultimate cost of compliance with applicable pipeline

integrity management regulations, as the cost will vary

significantly depending on the number and extent of any

repairs found to be necessary as a result of pipeline

integrity testing, but the results of these tests could cause

us to incur significant and unanticipated capital and

operating expenditures for repairs or upgrades deemed

necessary to ensure the safe and reliable operation of

our pipelines.

The 2011 Pipeline Safety Act amends the NGPSA and HLPSA

pipeline safety laws, requiring increased safety measures for

gas and hazardous liquids pipelines. Among other things,

the 2011 Pipeline Safety Act directs the Secretary of

Transportation to promulgate regulations relating to

expanded integrity management requirements, automatic

or remote-controlled valve use, excess flow valve use, leak

detection system installation, testing to confirm the material

strength of certain pipelines, and operator verification of

records confirming the maximum allowable pressure of

certain intrastate gas transmission pipelines. Additionally,

pursuant to one of the requirements of the 2011 Pipeline

Safety Act, in May 2016, PHMSA proposed rules that would,

if adopted, impose more stringent requirements for certain

gas lines, extend certain of PHMSA’s current regulatory

safety programs for gas pipelines beyond HCAs to cover

gas pipelines found in newly defined “moderate

consequence areas” that contain as few as five dwellings

within the potential impact area and require gas pipelines

installed before 1970 that were exempted from certain

pressure testing obligations to be tested to determine their

maximum allowable operating pressures (“MAOP”). Other

requirements proposed by PHMSA under the rulemaking

include: reporting to PHMSA in the event of certain MAOP

exceedances; strengthening PHMSA integrity management

requirements; considering seismicity in evaluating threats to

a pipeline; conducting hydrostatic testing for all pipeline

segments manufactured using longitudinal seam welds; and

using more detailed guidance from PHMSA in the selection

of assessment methods to inspect pipelines. The proposed

rulemaking also seeks to impose a number of requirements

on gathering lines. In January 2017, PHMSA finalized new

regulations for hazardous liquid pipelines that significantly

extend and expand the reach of certain PHMSA integrity

management requirements (i.e., periodic assessments,

repairs and leak detection), regardless of the pipeline’s

proximity to an HCA. The final rule also requires all pipelines

in or affecting an HCA to be capable of accommodating in-

line inspection tools within the next 20 years. In addition,

the final rule extends annual and accident reporting

requirements to gravity lines and all gathering lines and also

imposes inspection requirements on pipelines in areas

affected by extreme weather events and natural disasters,

such as hurricanes, landslides, floods, earthquakes, or other

similar events that are likely to damage infrastructure

PHMSA regularly revises its pipeline safety regulations. For

example, in June 2016, the President signed the Protecting

our Infrastructure of Pipelines and Enhancing Safety Act of

2016 (the “2016 PIPES Act”) into law. The 2016 PIPES Act

reauthorizes PHMSA through 2019, and facilitates greater

pipeline safety by providing PHMSA with emergency order

authority, including authority to issue prohibitions and

safety measures on owners and operators of gas or

hazardous liquid pipeline facilities to address imminent

hazards, without prior notice or an opportunity for a

hearing, as well as enhanced release reporting requirements,

requiring a review of both natural gas and hazardous liquid

integrity management programs, and mandating the

creation of a working group to consider the development of

an information-sharing system related to integrity risk

analyses. The 2016 PIPES Act also requires that PHMSA

publish periodic updates on the status of those mandates

outstanding from the 2011 Pipeline Safety Act PHMSA has

recently published three parts of its so-called “Mega Rule,”

including rules focused on: the safety of gas transmission

pipelines, the safety of hazardous liquid pipelines and

enhanced emergency order procedures. PHMSA finalized

the first part of the rule, which primarily addressed

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	105

maximum operating pressure and integrity management

near HCAs for onshore gas transmission pipelines, in

October 2019. PHMSA finalized the second part of the rule,

which extended federal safety requirements to onshore gas

gathering pipelines with large diameters and high operating

pressures, in November 2021. PHMSA published the final of

the three components of the Mega Rule in August 2022,

which took effect in May 2023. The final rule applies to

onshore gas transmission pipelines, and clarifies integrity

management regulations, expands corrosion control

requirements, mandates inspection after extreme weather

events, and updates existing repair criteria for both HCA

and non-HCA pipelines. Finally, PHMSA published a Notice

of Proposed Rulemaking regarding more stringent gas

pipeline leak detection and repair requirements to reduce

natural gas emissions on May 18, 2023.

At this time, we cannot predict the cost of such

requirements, but they could be significant. Moreover,

federal and state legislative and regulatory initiatives

relating to pipeline safety that require the use of new or

more stringent safety controls or result in more stringent

enforcement of applicable legal requirements could subject

us to increased capital costs, operational delays and costs

of operation.

Moreover as of January 2023, the maximum civil penalties

PHMSA can impose are $257,664 per pipeline safety

violation per day, with a maximum of $2,576,627 for a

related series of violations. The safety enhancement

requirements and other provisions of the 2011 Pipeline

Safety Act as well as any implementation of PHMSA

regulations thereunder or any issuance or reinterpretation

of guidance by PHMSA or any state agencies with respect

thereto could require us to install new or modified safety

controls, pursue additional capital projects or conduct

maintenance programs on an accelerated basis, any or all of

which tasks could result in our incurring increased

operating costs that could have a material adverse effect

on our results of operations or financial position. States are

also pursuing regulatory programs intended to safely build

pipeline infrastructure. The adoption of new or amended

regulations by PHMSA or the states that result in more

stringent or costly pipeline integrity management or safety

standards could have a significant adverse effect on us and

similarly situated midstream operators.

We are currently operating in a period of economic

uncertainty and capital markets disruption, which has been

significantly impacted by geopolitical instability due to

the ongoing military conflict between Russia and Ukraine,

and more recently, the Israel-Hamas war. Our business

may be adversely affected by any negative impact on the

global economy and capital markets resulting from the

conflict in Ukraine or any other geopolitical tensions.

U.S. and global markets are experiencing volatility and

disruption following the escalation of geopolitical tensions

and the start of the military conflict between Russia and

Ukraine. In February 2022, a full-scale military invasion of

Ukraine by Russian troops transpired. Although the length

and impact of the ongoing military conflict is highly

unpredictable, the conflict in Ukraine has led, and could

continue to lead, to market disruptions, including significant

volatility in commodity prices, credit and capital markets, as

well as supply chain interruptions.

Additionally, Russia’s prior annexation of Crimea, recent

recognition of two separatist republics in the Donetsk and

Luhansk regions of Ukraine and subsequent military

interventions in Ukraine have led to sanctions and other

penalties being levied by the United States, European Union

and other countries against Russia, Belarus, the Crimea

Region of Ukraine, the so-called Donetsk People’s Republic,

and the so-called Luhansk People’s Republic, including

agreement to remove certain Russian financial institutions

from the Society for Worldwide Interbank Financial

Telecommunication (“SWIFT”) payment system, expansive

bans on imports and exports of products to and from

Russia and bans on the exportation of U.S. denominated

banknotes to Russia or persons located there. Additional

potential sanctions and penalties have also been proposed

and/or threatened. Russian military actions and the

resulting sanctions could adversely affect the global

economy and financial markets and lead to instability and

lack of liquidity in capital markets, potentially making it

more difficult for us to obtain additional funds.

Additionally, on October 7, 2023, Hamas, a U.S. designated

terrorist organization, launched a series of coordinated

attacks from the Gaza Strip onto Israel. On October 8, 2023,

Israel formally declared war on Hamas, and the armed

conflict is ongoing as of the date of this filing. Hostilities

between Israel and Hamas could escalate and involve

surrounding countries in the Middle East. We are actively

monitoring the situation in Ukraine and Israel and assessing

their impact on our business. To date we have not

experienced any material interruptions in our infrastructure,

supplies, technology systems or networks needed to

support our operations given our operating areas are

exclusively located within the Central Region and the

Appalachian Basins of the U.S. We have no way to predict

the progress or outcome of the conflicts in Ukraine or Israel

or their impacts in Ukraine, Russia, Belarus, Israel or the

Gaza Strip as the conflicts, and any resulting government

reactions, are rapidly developing and beyond our control.

The extent and duration of the military actions, sanctions

and resulting market disruptions could be significant and

could potentially have substantial impact on the global

economy and our business for an unknown period of time.

Any of the aforementioned factors could affect our

business, financial condition and results of operations. Any

such disruptions may also magnify the impact of other risks

described in this Annual Report & Form 20-F.

Risks Relating to Our Financing, Acquisitions, Investment

and Indebtedness

Inflation may adversely affect us by increasing costs

beyond what we can recover through price increases and

limit our ability to enter into future debt financing.

Inflation can adversely affect us by increasing costs of

materials, equipment, labor and other services. In addition,

inflation is often accompanied by higher interest rates.

Continued inflationary pressures could impact our

profitability. Though we believe that the rates of inflation in

recent years, including the 12 months ended December 31,

2023

, have not had a significant impact on our operations, a

continued increase in inflation, including inflationary

pressure on labor, could result in increases to our operating

costs, and we may be unable to pass these costs on to our

customers. These inflationary pressures could also

adversely impact our ability to procure materials and

106	Diversified Energy Company PLC Annual Report and Form 20-F2023

equipment in a cost-effective manner, which could result in

reduced margins and production delays and, as a result, our

business, financial condition, results of operations and cash

flows could be materially and adversely affected. We

continue to undertake actions and implement plans to

address these inflationary pressures and protect the

requisite access to materials and equipment. With respect

to our costs of capital, our ABS Notes (as defined below)

are fixed-rate instruments (subject to adjustment pursuant

to the sustainability-linked features described under

Liquidity and Capital Resources) and as of December 31,

2023 we had $159 million outstanding on our Credit Facility.

Nevertheless, inflation may also affect our ability to enter

into future debt financing, including refinancing of our

Credit Facility or issuing additional SPV-level asset backed

securities, as high inflation may result in a relative increase

in the cost of debt capital.

We are taking efforts to mitigate inflationary pressures, by

working closely with other suppliers and service providers

to ensure procurement of materials and equipment in a

cost-effective manner. However, these mitigation efforts

may not succeed or may be insufficient.

Concerns about global economic growth have had a

significant adverse impact on global financial markets and

commodity prices. If the economic climate in the United

States or abroad deteriorates, worldwide demand for

petroleum products could diminish further, which could

impact the price at which natural gas, NGLs and oil can be

sold, which could affect our results of operations, financial

condition, cash flows and prospects.

There are risks inherent in our acquisitions of natural gas

and oil assets.

Acquisitions are an essential part of our strategy for

protecting and growing cash flow, particularly in relation to

the risk that some of our wells may have a higher than

anticipated production decline rate. Over the past several

years, we have undertaken a number of acquisitions of

natural gas and oil assets (and of companies holding such

assets), including, but not limited to the acquisition of

certain assets of Carbon Energy Corporation (the “Carbon

Acquisition”), the acquisition of certain assets and

infrastructure of EQT Corporation (the “EQT Acquisition”),

the acquisition of certain assets from Triad Hunter, LLC (the

“Utica Acquisition”), the acquisition of 51.25% working

interest in certain assets and infrastructure from Indigo

Minerals LLC (the “Indigo Acquisition”), the acquisition of

certain assets and infrastructure from Blackbeard Operating

LLC (the “Blackbeard Acquisition”), the acquisition of

51.25% working interest in certain assets, infrastructure,

equipment and facilities in conjunction with Oaktree from

Tanos Energy Holdings III, LLC (the “Tanos Acquisition”),

the acquisition of 51.25% working interest in certain assets,

infrastructure, equipment and facilities in conjunction with

Oaktree from Tapstone Energy Holdings LLC (the

“Tapstone Acquisition”), the acquisition of 52.5% working

interest in certain upstream assets and related facilities

within the Central Region from a private seller, in

conjunction with Oaktree (the “East Texas Assets

Acquisition”), the acquisition of certain upstream assets and

related infrastructure within the Central Region from Tanos

Energy Holdings II LLC (the “Tanos II Acquisition”) and the

acquisition of certain upstream assets and related gathering

infrastructure in the Central Region from ConocoPhillips

(the “ConocoPhillips Acquisition”). Our ability to complete

future acquisitions will depend on us being able to identify

suitable acquisition candidates and negotiate favorable

terms for their acquisition, in each case, before any

attractive candidates are purchased by other parties such

as private equity firms, some of whom have substantially

greater financial and other resources than we do. We may

face competition for attractive acquisition targets that may

also increase the price of the target business. As a result,

there is no assurance that we will always be able to source

and execute acquisitions in the future at

attractive valuations.

Furthermore, to further the Group’s growth, we have made

further acquisitions outside the Appalachian Basin, a region

in which we have developed our operational experience

into the Bossier Shale, the Haynesville Shale, the Barnett

Shale Play, and the Cotton Valley and Mid-Continent

producing areas. Accordingly, an acquisition in a new area

in which we lack experience may present unanticipated

risks and challenges that were not accounted for or

previously experienced. Ordinarily, our due diligence efforts

are focused on higher valued and material properties or

assets. Even an in-depth review of all properties and

records may not reveal all existing or potential problems,

nor will such review always permit a buyer to become

sufficiently familiar with the properties to fully assess their

deficiencies and capabilities. Generally, physical inspections

are not performed on every well or facility, and structural or

environmental problems are not necessarily observable

even when an inspection is undertaken.

There can be no assurance that our prior acquisitions or any

other potential acquisition will perform operationally as

anticipated or be profitable. We could fail to appropriately

value any acquired business and the value of any business,

company or property that we acquire or invest in may

actually be less than the amount paid for it or its estimated

production capacity. We may be required to assume pre-

closing liabilities with respect to an acquisition, including

known and unknown title, contractual, and environmental

and decommissioning liabilities, and may acquire interests

in properties on an “as is” basis without recourse to the

seller of such interest or the seller may have limited

resources to provide post-sale indemnities.

In addition, successful acquisitions of gas and oil assets

require an assessment of a number of factors, including

estimates of recoverable reserves, the time of recovering

reserves, exploration potential, future natural gas, NGLs and

oil prices and operating costs. Such assessments are

inexact, and we cannot guarantee that we make these

assessments with a high degree of accuracy. In connection

with assessments, we perform a review of the acquired

assets. However, such a review will not reveal all existing or

potential problems. Furthermore, review may not permit us

to become sufficiently familiar with the assets to fully

assess their deficiencies and capabilities.

Integrating operations, technology, systems, management,

back office personnel and pre- or post-completion costs for

future acquisitions may prove more difficult or expensive

than anticipated, thereby rendering the value of any

company or assets acquired less than the amount paid. We

may also take on unexpected liabilities which are uncapped,

have to undertake unanticipated capital expenditures in

connection with a new acquisition or provide uncapped

liabilities in connection with the purchase and sale of assets,

which are customary in such agreements. The integration of

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	107

acquired businesses or assets requires significant time and

effort on the part of our management. Following such

integration efforts, prior acquisitions may still not achieve

the level of financial or operational performance that was

anticipated when they were acquired. In addition, the

integration of new acquisitions can be difficult and disrupt

our own business because our operational and business

culture may differ from the cultures of the acquired

businesses, unpopular cost-cutting measures may be

required, internal controls may be more difficult to maintain

and control over cash flows and expenditures may be

difficult to establish. If we encounter any of the foregoing

issues in relation to one of our acquisitions this could have a

material adverse effect on our business, results of

operations, financial condition, cash flows or prospects.

We may be unable to make attractive acquisitions or

successfully integrate acquired businesses, and any

inability to do so may disrupt our business and hinder our

ability to grow.

In the future we may make acquisitions of businesses that

complement or expand our current business. However, we

may not be able to identify attractive acquisition

opportunities. Even if we do identify attractive acquisition

opportunities, we may not be able to complete the

acquisition or do so on commercially acceptable terms.

The success of any completed acquisition will depend on

our ability to integrate effectively the acquired business

into our existing operations. The process of integrating

acquired businesses may involve unforeseen difficulties and

may require a disproportionate amount of our managerial

and financial resources. In addition, possible future

acquisitions may be larger and for purchase prices

significantly higher than those paid for earlier acquisitions.

No assurance can be given that we will be able to identify

additional suitable acquisition opportunities, negotiate

acceptable terms, obtain financing for acquisitions on

acceptable terms or successfully acquire identified targets.

Our failure to achieve consolidation savings, to integrate

the acquired businesses and assets into our existing

operations successfully or to minimize any unforeseen

operational difficulties could have a material adverse effect

on our financial condition and results of operations.

Our Credit Facility also limits our ability to incur certain

indebtedness, which could indirectly limit our ability to

engage in acquisitions of businesses.

We may not have good title to all our assets and licenses.

Although we believe that we take due care and conduct

due diligence on new acquisitions in a manner that is

consistent with industry practice, there can be no assurance

that we have good title to all our assets and the rights to

develop and produce natural gas and oil from our assets.

Such reviews are inherently incomplete and it is generally

not feasible to review in depth every individual well or field

involved in each acquisition. There can be no assurance that

any due diligence carried out by us or by third parties on

our behalf in connection with any assets that we acquire

will reveal all of the risks associated with those assets, and

the assets may be subject to preferential purchase rights,

consents and title defects that were not apparent at the

time of acquisition. We may acquire interests in properties

on an “as is” basis without recourse to the seller of such

interest or the seller may have limited resources to provide

post-sale indemnities. In addition, changes in law or change

in the interpretation of law or political events may arise to

defeat or impair our claim to certain properties which we

currently own or may acquire which could result in a

material adverse effect on our business, results of

operations, financial condition, cash flows or prospects.

The issuance of additional ordinary shares in the Group in

connection with future acquisitions or other growth

opportunities, any share incentive or share option plan or

otherwise may dilute all other shareholdings.

We may seek to raise financing to fund future acquisitions

and other growth opportunities. We may, for these and

other purposes, issue additional equity or convertible equity

securities. As a result, existing holders of ordinary shares

may suffer dilution in their percentage ownership or the

market price of the ordinary shares may be

adversely affected.

As of December 31, 2023, we have issued options under our

equity incentive plans to employees and executive directors

for a total of 220,441 new ordinary shares of the Group, all

of which are currently outstanding, and have also entered

into restricted stock unit agreements and performance

stock unit agreements with certain employees, of which

307,576 restricted stock units and 612,482 performance

stock units are outstanding. We may, in the future, issue

further options and/or warrants to subscribe for new

ordinary shares to certain advisers, employees, directors,

senior management and/or consultants of the Group. The

exercise of any such options would result in a dilution of the

shareholdings of other investors. Additionally, although we

currently have no plans for an offering of ordinary shares, it

is possible that we may decide to offer additional ordinary

shares in the future. Subject to any applicable pre-emption

rights, any future issues of ordinary shares by the Group

may have a dilutive effect on the holdings of shareholders

and could have a material adverse effect on the market

price of ordinary shares as a whole.

Restrictions in our existing and future debt agreements

could limit our growth and our ability to engage in

certain activities.

Our Credit Facility contains a number of significant

covenants that may limit our ability to, among other things:

—incur additional indebtedness;

—incur liens;

—sell assets;

—make certain debt payments;

—enter into agreements that restrict or prohibit the

payment of dividends;

—limits our subsidiaries’ ability to make certain payments

with respect to their equity, based on the pro forma

effect thereof on certain financial ratios, which would be

the source of distributable profits from which we may

issue a dividend; and

—conduct hedging activities.

In addition, our Credit Facility requires us to maintain

compliance with certain financial covenants.

We may also be prevented from taking advantage of

business opportunities that arise because of the limitations

from the restrictive covenants under our Credit Facility.

These restrictions may limit our ability to obtain future

108	Diversified Energy Company PLC Annual Report and Form 20-F2023

financings to withstand a future downturn in our business

or the economy in general, or to otherwise conduct

necessary corporate activities.

A breach of any covenant in our Credit Facility will result in

a default under the agreement and may result in an event of

default under the Credit Facility if such default is not cured

during any applicable grace period. An event of default, if

not waived, could result in acceleration of the indebtedness

outstanding under our Credit Facility and in an event of

default with respect to, and an acceleration of, the

indebtedness outstanding under any other debt

agreements to which we are a party. Any such accelerated

indebtedness would become immediately due and payable.

If that occurs, we may not be able to make all of the

required payments or borrow sufficient funds to refinance

such indebtedness. Even if new financing were available at

that time, it may not be on terms that are acceptable to us.

Any significant reduction in our borrowing base under our

Credit Facility as a result of periodic borrowing base

redeterminations or otherwise may negatively impact our

ability to fund our operations.

Our Credit Facility limits the amounts we can borrow up to

a borrowing base amount, which the lenders, in their sole

discretion, unilaterally determine based upon our reserve

reports for the applicable period and other data and

reports. Such determinations will be made on a regular

basis semi-annually (each a “Scheduled Redetermination”)

and at the option of the lenders with more than 66.6% of

the loans and commitments under the Credit Facility, no

more than one time in between each Scheduled

Redetermination. As of the date hereof, our borrowing base

is $305 million.

In the future, we may not be able to access adequate

funding under our Credit Facility as a result of a decrease in

our borrowing base due to the issuance of new

indebtedness, the outcome of a borrowing base

redetermination, or an unwillingness or inability on the part

of lending counterparties to meet their funding obligations

and the inability of other lenders to provide additional

funding to cover a defaulting lender’s portion. Declines in

commodity prices from their current levels could result in a

determination to lower the borrowing base and, in such a

case, we could be required to repay any indebtedness in

excess of the redetermined borrowing base. As a result, we

may be unable to make acquisitions or otherwise carry out

business plans, which could have a material adverse effect

on our business, results of operations, financial condition,

cash flows or prospects.

The securitizations of our limited purpose, bankruptcy-

remote, wholly owned subsidiaries may expose us to

financing and other risks, and there can be no assurance

that we will be able to access the securitization market in

the future, which may require us to seek more

costly financing.

Through limited purpose, bankruptcy-remote, wholly

owned subsidiaries (“SPVs”), we have securitized and

expect to securitize in the future, certain of our assets to

generate financing. In such transactions, we convey a pool

of assets to an SPV, that, in turn, issues certain securities or

enters into certain debt agreements, such as our Term

Loan I. The securities issued by the SPVs and the Term

Loan I are each collateralized by a pool of assets. In

exchange for the transfer of finance receivables to the SPV,

we typically receive the cash proceeds from the sale of the

securities or entering into term loans.

Although our SPVs have successfully completed

securitizations in connection with the Term Loan I, the ABS

I Notes, ABS II Notes, ABS III Notes, ABS IV Notes, ABS V

Notes and ABS VI Notes (each as defined herein), there can

be no assurance that we, through our SPVs, will be able to

complete additional securitizations, particularly if the

securitization markets become constrained. In addition, the

value of any securities that our limited purpose,

bankruptcy-remote, wholly owned subsidiaries retain in our

securitizations, including securities retained to comply with

applicable risk retention rules, might be reduced or, in some

cases, eliminated as a result of an adverse change in

economic conditions or the financial markets. In addition,

our Term Loan I, ABS I Notes, ABS II Notes, ABS III Notes,

ABS IV Notes, ABS V Notes and ABS VI Notes are subject

to customary accelerated amortization events, including

events tied to the failure to maintain stated debt service

coverage ratios.

If it is not possible or economical for us to securitize our

assets in the future, we would need to seek alternative

financing to support our operations and to meet our

existing debt obligations, which may be less efficient and

more expensive than raising capital via securitizations and

may have a material adverse effect on our results of

operations, financial condition, cash flows and liquidity.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	109

img_Pikeville Selects-25.jpg

An increase in interest rates would increase the cost of

servicing our indebtedness and could reduce our

profitability, decrease our liquidity and impact

our solvency.

Our Credit Facility provides for, and our future debt

agreements may provide for, debt incurred thereunder to

bear interest at variable rates. As of December 31, 2023, we

had $159 million outstanding on our Credit Facility.

Increases in interest rates would increase the cost of

servicing indebtedness under our Credit Facility or under

future debt agreements subject to interest at variable rates,

and materially reduce our profitability, decrease our

liquidity and impact our solvency.

Our hedging activities could result in financial losses or

could reduce our net income.

To achieve more predictable cash flows, we employ a

hedging strategy involving opportunistically hedging a

majority of our first two years of production as well as

hedging a significant percentage of production beyond our

first two years of forecasted production. Even so, the

remainder of our production that is unhedged is exposed to

the continuing and prolonged declines in the prices of

natural gas, NGLs and oil. Our results of operations and

financial condition would be negatively impacted if the

prices of natural gas, NGLs or oil were to remain depressed

or decline materially from current levels. To achieve more

predictable cash flows and to reduce our exposure to

fluctuations in the prices of natural gas, NGLS and oil, we

may enter into additional hedging arrangements for a

significant portion of our production.

Our derivative contracts may result in substantial gains or

losses. For example, we reported an operating profit of

$1,161 million for the year ended December 31, 2023,

compared with an operating loss of $671 million for the year

ended December 31, 2022 and $467 million for the year

ended December 31, 2021. While our earnings are impacted

by a variety of factors as described in Results of

Operations, a key driver of our year over year change from

an operating loss to profit was attributable to a change of

$1,767 million in the mark-to-market valuation adjustment

on our derivative financial instrument valuations to $906

million gain in 2023 from $861 million loss in

2022

. There

can be no assurance that we will not realize additional

losses due to our hedging activities in the future. In

addition, if we enter into any derivative contracts and

experience a sustained material interruption in our

production, we might be forced to satisfy all or a portion of

our hedging obligations without the benefit of the cash

flows from our sale of the underlying physical commodity,

resulting in a substantial diminution of our liquidity. Our

ability to use hedging transactions to protect us from future

natural gas, NGL and oil price volatility will be dependent

upon natural gas, NGL and oil prices at the time we enter

into future hedging transactions and our future levels of

hedging and, as a result, our future net cash flows may be

more sensitive to commodity price changes. In addition, if

commodity prices remain low, we will not be able to

replace our hedges or enter into new hedges at

favorable prices.

Our price hedging strategy and future hedging transactions

will be determined at our discretion, subject to the terms of

certain agreements governing our indebtedness. The prices

at which we hedge our production in the future will be

dependent upon commodity prices at the time we enter

into these transactions, which may be substantially higher

or lower than current prices. Accordingly, our price hedging

strategy may not protect us from significant declines in

prices received for our future production. Conversely, our

hedging strategy may limit our ability to realize cash flows

from commodity price increases. It is also possible that a

substantially larger percentage of our future production will

not be hedged as compared with the next few years, which

would result in our natural gas, NGL and oil revenues

becoming more sensitive to commodity price fluctuations.

The failure of our hedge counterparties to meet their

obligations to us may adversely affect our financial results.

An attendant risk exists in hedging activities that the

counterparty in any derivative transaction cannot or will not

perform under the instrument and that we will not realize

the benefit of the hedge. Disruptions in the financial

markets could lead to sudden decreases in a counterparty’s

liquidity, which could make them unable to perform under

the terms of the derivative contract and we may not be

able to realize the benefit of the derivative contract. Any

default by the counterparty to these derivative contracts

when they become due would have a material adverse

effect on our results of operations, financial condition, cash

flows and prospects.

We may not be able to enter into commodity derivatives

on favorable terms or at all.

To achieve a more predictable cash flow, we employ a

hedging strategy involving opportunistically hedging a

majority of our first two years of production as well as

hedging a significant percentage of production beyond our

first two years of forecasted production. If we are unable to

maintain sufficient hedging capacity with our

counterparties, we could have greater exposure to changes

in commodity prices and interest rates, which could have a

material adverse impact on our business, results of

operations, financial condition, cash flows or prospects.

Risks Relating to Legal, Tax, Environmental and

Regulatory Matters

We are subject to regulation and liability under

environmental, health and safety regulations, the violation

of which may affect our financial condition and operations.

We operate in an industry that has certain inherent hazards

and risks, and consequently we are subject to stringent and

comprehensive laws and regulations, especially with regard

to the protection of health, safety and the environment. For

example, we are subject to laws and regulations related to

occupational safety and health, hydraulic fracturing

activities, air emissions, soil and water quality, the

protection of threatened and endangered plant and animal

species, biodiversity and ecosystems, and the safety of our

assets and employees. Although we believe that we have

adequate procedures in place to mitigate operational risks,

there can be no assurances that these procedures will be

adequate to address every potential health, safety and

environmental hazard, and a failure to adequately mitigate

risks may result in loss of life, injury, or adverse impacts on

the health of employees, contractors and third-parties or

the environment. Any failure by us or one of our

subcontractors, whether inadvertent or otherwise, to

comply with applicable legal or regulatory requirements

may give rise to civil, administrative and/or criminal

liabilities, civil fines and penalties, delays or restrictions in

110	Diversified Energy Company PLC Annual Report and Form 20-F2023

acquiring or disposing of assets and/or delays in securing

or maintaining required permits, licenses and approvals.

Further, a lack of regulatory compliance may lead to denial,

suspension, or termination of permits, licenses, or approvals

that are required to operate our sites or could result in

other operational restrictions or obligations. Our health,

safety and environmental policies require us to observe

local, state and national legal and regulatory requirements

and to apply generally accepted industry best practices

where legislation or regulation does not exist.

The terms and conditions of licenses, permits, regulatory

orders, approvals or permissions may include more

stringent operational, environmental and/or health and

safety requirements. Obtaining development or production

licenses and permits may become more difficult or may be

delayed due to federal, regional, state or local

governmental constraints, considerations, or requirements

on issuing. Furthermore, third-parties such as environmental

NGOs may administratively or judicially contest or protest

licenses and permits already granted by relevant authorities

or applications for the same and operations may be subject

to other administrative or judicial challenges.

In addition, under certain environmental laws and

regulations, we could be subject to joint and several strict

liability for the removal or remediation of previously

released materials, pollution, or property contamination

regardless of whether we were responsible for the release

or contamination or whether the operations were in

compliance with all applicable laws at the time those

actions were taken. Private parties, including the owners of

properties on or adjacent to well sites and facilities where

petroleum hydrocarbons or wastes are taken for

reclamation or disposal, may also have the right to pursue

legal actions as well as to seek damages for non-

compliance with environmental laws and regulations or for

personal injury or property damage. In addition, the risk of

accidental spills or releases of pollutants or contaminants

could expose us to significant liabilities that could have a

material adverse effect on our business, financial condition

and results of operations.

We incur, and expect to continue to incur, capital and

operating costs in an effort to comply with increasingly

complex operational health and safety and environmental

laws and regulations. New laws and regulations, the

imposition of more stringent requirements in permits and

licenses, increasingly strict enforcement of, or new

interpretations of, existing laws, regulations and permits

and licenses, or the discovery of previously unknown

contamination or hazards may require further costly

expenditures to, for example:

—modify operations, including an increase in plugging and

abandonment operations;

—install or upgrade pollution or emissions

control equipment;

—perform site clean ups, including the remediation and

reclamation of gas and oil sites;

—curtail or cease certain operations;

—provide financial securities, bonds, and/or take out

insurance; or

—pay fees or fines or make other payments for pollution,

discharges to the environment or other breaches of

environmental or health and safety requirements or

consent agreements with regulatory agencies.

We cannot predict with any certainty the full impact of any

new laws, regulations, or policies on our operations or on

the cost or availability of insurance to cover the risks

associated with such operations. The costs of such

measures and liabilities related to potential operational

health and safety or environmental risks associated with the

Group may increase, which could materially and adversely

affect our business, results of operations, financial

condition, cash flows or prospects. In addition, it is not

possible to predict what future operational health and

safety or environmental laws and regulations will be

enacted or how current or future operational, health, safety

or environmental laws and regulations will be applied or

enforced. We may have to incur significant expenditure for

the installation and operation of additional systems and

equipment for monitoring and carry out remedial measures

in the event that operational health and, safety and

environmental regulations become more stringent or costly

reform is implemented by regulators. Any such expenditure

may have a material adverse effect on our business, results

of operations, financial condition, cash flows or prospects.

No assurance can be given that compliance with

occupational health and safety and environmental laws or

regulations in the regions where we operate will not result

in a curtailment of production or a material increase in the

cost of production or development activities.

Increasing attention to sustainability matters may impact

our business and financial results.

Increasing attention has been given to corporate activities

related to sustainability matters in public discourse and the

investment community. A number of advocacy groups,

both domestically and internationally, have campaigned for

governmental and private action to promote change at

public companies related to sustainability matters, including

through the investment and voting practices of investment

advisers, public pension funds, activist investors,

universities and other members of the investing community.

These activities include increasing attention and demands

for action related to climate change, advocating for

changes to companies’ board of directors and promoting

the use of alternative forms of energy. These activities may

result in demand shifts for oil and natural gas products and

additional governmental investigations and private ligation

against us. In addition, a failure to comply with evolving

investor or customer expectations and standards or if we

are perceived to not have responded appropriately to the

growing concern for sustainability issues, regardless of

whether there is a legal requirement to do so, could cause

reputational harm to our business, increase our risk of

litigation, and could have a material adverse effect on our

results of operation.

In addition, organizations that provide information to

investors on corporate governance and related matters

have developed ratings systems for evaluating companies

on their approach to sustainability matters. These ratings

are used by some investors to inform their investment and

voting decisions. Unfavorable sustainability ratings may

lead to increased negative investor sentiment toward us

and our industry and to the diversion of investment to other

companies or industries, which could have a negative

impact on our stock price and our access to and costs of

capital. Also, institutional lenders may decide not to provide

funding for oil and natural gas companies based on climate

change related concerns, which could affect our access to

capital for potential growth projects.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	111

The current U.S. administration, acting through the

executive branch and/or in coordination with Congress,

could enact rules and regulations that impose more

onerous permitting and other costly environmental, health

and safety requirements on our operations.

Governmental, scientific and public concern over the threat

of climate change arising from GHG emissions has resulted

in increasing political risks in the United States, including

climate change-related commitments expressed by some

political candidates who are now, or may in the future be, in

political office.

While our operations are largely not conducted on federal

lands, we may in the future consider acquisitions of natural

gas and oil assets located in areas in which the

development of such assets would require permits and

authorizations to be obtained from or issued by federal

agencies. To conduct these operations, we may be required

to file applications for permits, seek agency authorizations

and comply with various other statutory and regulatory

requirements. Further, new oil and gas leasing on public

lands has been the subject of recent proposed reforms,

including bans in certain areas, raising royalty rates and

implementing stricter standards for entities seeking to

purchase oil and gas leases. Complying with any of these

requirements may adversely affect our ability to conduct

operations at the costs and in the time periods anticipated,

and may consequently adversely impact our anticipated

returns from our operations.

Presidential or congressional actions could adversely affect

our operations by restricting the lands available for

development and/or access to permits required for such

development, or by imposing additional and costly

environmental, health and safety requirements. Any such

measures or increased costs could have a material adverse

effect on our business, results of operations, financial

condition, cash flows or prospects.

Our operations are dependent on our compliance with

obligations under permits, licenses, contracts and field

development plans.

Our operations must be carried out in accordance with the

terms of permits, licenses, operating agreements, annual

work programs and budgets. Fines, penalties, or

enforcement actions may be imposed and a permit or

license may be suspended or terminated if a permit or

license holder, or party to a related agreement, fails to

comply with its obligations under such permit, license or

agreement, or fails to make timely payments of levies and

taxes for the licensed activity, or fails to provide the

required geological information or meet other reporting

requirements. It may from time to time be difficult to

ascertain whether we have complied with obligations under

permits or licenses as the extent of such obligations may be

unclear or ambiguous and regulatory authorities in

jurisdictions in which we do business, or in which we may

do business in the future, may not be forthcoming with

confirmatory statements that work obligations have been

fulfilled, which can lead to further operational uncertainty.

In addition, we and our commercial partners, as applicable,

have obligations to operate assets in accordance with

specific requirements under certain licenses and related

agreements, field development agreements, laws and

regulations. If we or our partners were to fail to satisfy such

obligations with respect to a specific field, the license or

related agreements for that field may be suspended,

revoked or terminated. Although we have in the past

acquired and may in the future acquire shale assets, a

significant source of our natural gas and crude oil remains

conventional wells. In some instances, these conventional

wells are located on the same property as unconventional

wells that produce shale oil. In these cases, the rights to

access the shale layers of the property will typically be

conditioned on the ongoing productivity of conventional

wells on the property. Furthermore, the shale rights may be

owned by a third party, and in such instances, we will enter

into a joint use agreement with the third party. This joint use

agreement may stipulate that in consideration for permission

to operate the conventional wells, we are to use reasonable

efforts to maintain production so that the third party retains

the shale licenses. If we fail to maintain production in the

conventional wells, under the joint use agreement, we may

be liable to the third party for replacing the lost land rights.

The relevant authorities are typically authorized to, and do

from time to time, inspect to verify compliance by us or our

commercial partners, as applicable, with relevant laws and

the licenses or the agreements pursuant to which we

conduct our business. There can be no assurance that the

views of the relevant government agencies regarding the

development of the fields that we operate or the compliance

with the terms of the licenses pursuant to which we conduct

such operations will coincide with our views, which might

lead to disagreements that may not be resolved.

The suspension, revocation, withdrawal or termination of

any of the permits, licenses or related agreements pursuant

to which we may conduct business, as well as any delays in

the continuous development of or production at our fields

caused by the issues detailed above could materially and

adversely affect our business, results of operations, financial

condition, cash flows or prospects. In addition, failure to

comply with the obligations under the permits, licenses or

agreements pursuant to which we conduct business,

whether inadvertent or otherwise, may lead to fines,

penalties, restrictions, enforcement actions brought by

governmental authorities, withdrawal of licenses and

termination of related agreements.

We do not insure against certain risks and our insurance

coverage may not be adequate for covering losses

arising from potential operational hazards and

unforeseen interruptions.

We insure our operations in accordance with industry

practice and plan to continue to insure the risks we

consider appropriate for our needs and circumstances.

However, we may elect not to have insurance for certain

risks, due to the high premium costs associated with

insuring those risks or for various other reasons, including

an assessment in some cases that the risks are remote.

Our insurance may not be adequate to cover all losses or

liabilities we may suffer. We cannot assure that we will be

able to obtain insurance coverage at reasonable rates (or at

all), or that any coverage we or the relevant operator

obtain, and any proceeds of insurance, will be adequate and

available to cover any claims arising. We may become

subject to liability for pollution, blow-outs or other hazards

against which we have not insured or cannot insure,

including those in respect of past activities for which we

were not responsible. Any indemnities we may receive from

sub-contractors, operators or joint venture partners may be

difficult to enforce if such sub-contractors, operators or

joint venture partners lack adequate resources.

112	Diversified Energy Company PLC Annual Report and Form 20-F2023

Operational insurance policies are usually placed in one

year contracts and the insurance market can withdraw

cover for certain risks due to events occurring in other

parts of the industry, thus greatly increasing the costs of

risk transfer. For example, in September 2018, a gas pipeline

operated by another midstream company exploded in

Beaver County, Pennsylvania, a state in which we have

operations. The explosion resulted in the destruction of

residential property and motor vehicles as well as the

evacuation of nearby households. Catastrophic events such

as these may cause the insurance costs for our midstream

operations to rise, despite us not being involved in the

catastrophic event. In the event that insurance coverage is

not available or our insurance is insufficient to fully cover

any losses, including losses incurred due to lost revenues

resulting from third party operations or processing plants,

claims and/or liabilities incurred, or indemnities are difficult

to enforce, our business and operations, financial results or

financial position may be disrupted and adversely affected.

The payment by our insurers of any insurance claims may

result in increases in the premiums payable by us for our

insurance coverage and could adversely affect our financial

performance. In the future, some or all of our insurance

coverage may become unavailable or

prohibitively expensive.

Our internal systems and website may be subject to

intentional and unintentional disruption, and our

confidential information may be misappropriated, stolen

or misused, which could adversely impact our reputation

and future sales.

We have faced, and may in the future continue to face,

cyber-attacks and data security breaches. Such cyber-

attacks and breaches are designed to penetrate our

network security or the security of our internal systems,

misappropriate proprietary information and/or cause

interruptions to our services, and we expect to continue to

face similar threats in the future. We cannot guarantee that

we will be able to successfully prevent all attacks in the

future. Such future attacks could include hackers obtaining

access to our systems, the introduction of malicious

computer code or denial of service attacks. If an actual or

perceived breach of our network security occurs, it could

adversely affect our business or reputation, and may expose

us to the loss of information, litigation and possible liability.

An actual security breach could also impair our ability to

operate our business and provide products and services to

our customers. Additionally, malicious attacks, including

cyber-attacks, may damage our assets, prevent production

at our producing assets and otherwise significantly affect

corporate activities. For example, we utilize electronic

monitoring of meters and flow rate devices to monitor

pressure build-up in our production wells. If there were a

cyber-attack that penetrated our monitoring systems such

that they provided false readings, this could result in an

unknown pressure build-up, creating a dangerous situation

which could end up in an explosion. As techniques used to

obtain unauthorized access to or to sabotage systems

change frequently and may not be known until launched

against us or our third-party service providers, we may be

unable to anticipate or implement adequate measures to

protect against these attacks and our service providers may

likewise be unable to do so. Such an outcome would have a

material adverse impact on our business, results of

operations, financial condition, cash flows or prospects.

In addition, confidential or financial payment information

that we maintain may be subject to misappropriation, theft

and deliberate or unintentional misuse by current or former

employees, third-party contractors or other parties who

have had access to such information. Any such

misappropriation and/or misuse of our information could

result in the Group, among other things, being in breach of

certain data protection requirements and related legislation

as well as incurring liability to third parties. We expect that

we will need to continue closely monitoring the accessibility

and use of confidential information in our business, educate

our employees and third-party contractors about the risks

and consequences of any misuse of confidential information

and, to the extent necessary, pursue legal or other remedies

to enforce our policies and deter future misuse. If our

confidential information is misappropriated, stolen or

misused as a result of a disruption to our website or internal

systems this could have a material adverse effect on our

business, results of operations, financial condition, cash

flows or prospects.

Although we maintain insurance to protect against losses

resulting from certain of data protection breaches and

cyber-attacks, our coverage for protecting against such

risks may not be sufficient.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	113

Our operations are subject to the risk of litigation.

From time to time, we may be subject, directly or indirectly,

to litigation arising out of our operations and the regulatory

environments in our areas of operations. Historically,

categories of litigation that we have faced included actions

by royalty owners over payment disputes, personal injury

claims and property related claims, including claims over

property damage, trespass or nuisance. Although we

currently face no material litigation that is reasonably

expected to have an adverse material impact for which we

are not sufficiently indemnified or insured, damages

claimed under such litigation in the future may be material

or may be indeterminate, and the outcome of such

litigation, if determined adversely to us, could individually

or in the aggregate, be reasonably expected to have a

material and adverse effect on our business, financial

position or results of operations. While we assess the merits

of each lawsuit and defend ourselves accordingly, we may

be required to incur significant expenses or devote

significant resources to defend against such litigation. In

addition, the adverse publicity surrounding such claims may

have a material adverse effect on our business.

We are subject to certain tax risks.

Any change in our tax status or in taxation legislation in the

United Kingdom or the United States could affect our

ability to provide returns to shareholders. Statements in this

document concerning the taxation of holders of our

ordinary shares are based on current law and practice,

which is subject to change.

We are subject to income taxes in the United Kingdom and

the United States, and there can be no certainty that the

current taxation regime in the United Kingdom, the United

States or other jurisdictions within which we currently

operate or may operate in the future will remain in force or

that the current levels of corporation taxation will remain

unchanged. For example, the U.S. government has imposed

a minimum tax on corporations and proposed and may

enact significant changes to the taxation of business

entities including, among others, an increase in the U.S.

federal income tax rate applicable to corporations, like us,

and surtaxes on certain types of income. Certain U.S.

localities also maintain a severance tax or impact fee on the

removal of oil and natural gas from the ground and such tax

rates may be increased or new severance taxes or impact

fees may be implemented. In addition, in response to

current global events and consumer hardship, the United

Kingdom announced on May 26, 2022 a new “Energy Profits

Levy” on oil and gas exploration and production companies

operating in the United Kingdom and the UK Continental

Shelf at a rate of 25% (subsequently increased to 35%). As

we do not operate our exploration, production or extraction

activities in the United Kingdom or in the UK Continental

Shelf, we do not expect the Energy Profits Levy to impact

our headline corporation tax rate in the United Kingdom,

however, the taxation of energy companies remains

uncertain, particularly in the context of current global

events, and the future stability of such tax regimes cannot

be guaranteed.

Our domestic and international tax liabilities are subject to

the allocation of expenses in differing jurisdictions. Our

effective tax rate could be adversely affected by changes in

the mix of earnings and losses in taxing jurisdictions with

differing statutory tax rates, certain non-deductible

expenses, the valuation of deferred tax assets and liabilities

and changes in federal, state or international tax laws and

accounting principles. Increases in our effective tax rate

could materially affect our net financial results. Although we

believe that our income tax liabilities are reasonably

estimated and accounted for in accordance with applicable

laws and principles, an adverse resolution of one or more

uncertain tax positions in any period could have a material

adverse effect on our business, results of operations,

financial condition, cash flows or prospects.

In the past we have been able to offset a large portion of

our U.S. federal income tax burden with marginal well tax

credits that are available to qualified producers who

operate lower-volume wells during a low commodity pricing

environment. There can be no assurance that there will be

no amendment to the existing taxation laws applicable to us,

which may have a material adverse effect on our financial

position. Our ability to utilize marginal well tax credits in the

United States could be or become subject to limitations (for

example, if we are deemed to undergo an “ownership

change” for applicable U.S. federal income tax purposes).

The nature and amount of tax that we expect to pay and

the reliefs expected to be available to us are each

dependent upon several assumptions, any one of which

may change and which would, if so changed, affect the

nature and amount of tax payable and reliefs available. In

particular, the nature and amount of tax payable may be

dependent on the availability of relief under tax treaties and

is subject to changes to the tax laws or practice in any of

the jurisdictions we currently are subject to or may be

subject to in the future. Any limitation in the availability of

relief under these treaties, any change in the terms of any

such treaty or any changes in tax law, interpretation or

practice could increase the amount of tax payable by us.

Finally, because we are an entity incorporated in the United

Kingdom that is treated as a U.S. corporation for all

purposes of U.S. federal income tax law, any changes in U.S.

federal income tax law could negatively impact our

effective tax rate and cash flows, which could cause our

business, results of operations, financial condition, cash

flows or prospects to be materially adversely affected.

The taxation of an investment in our ordinary shares

depends on the individual circumstances of the holders of

our ordinary shares. Holders of our ordinary shares are

strongly advised to consult their professional tax advisers.

Tax legislation may be enacted in the future that could

negatively impact our current or future tax structure and

effective tax rates.

Long-standing international tax initiatives that determine

each country’s jurisdiction to tax cross-border international

trade and profits are evolving as a result of, among other

things, initiatives such as the Anti-Tax Avoidance Directives,

as well as the Base Erosion and Profit Shifting reporting

requirements, mandated and/or recommended by the EU,

G8, G20 and Organization for Economic Cooperation and

Development, including the imposition of a minimum global

effective tax rate for multinational businesses regardless of

the jurisdiction of operation and where profits are

generated (Pillar Two). As these and other tax laws and

related regulations change (including changes in the

interpretation, approach and guidance of tax authorities),

our financial results could be materially impacted. Given the

unpredictability of these possible changes and their

114	Diversified Energy Company PLC Annual Report and Form 20-F2023

potential interdependency, it is difficult to assess whether

the overall effect of such potential tax changes would be

cumulatively positive or negative for our earnings and

cash flow, but such changes could adversely affect our

financial results.

Risks Relating to Our Ordinary Shares

Our ordinary shares are subject to market price volatility

and the market price may decline disproportionately in

response to developments that are unrelated to our

operating performance.

The market price of our ordinary shares has been, and may

in the future be, volatile and subject to wide fluctuations as

a result of a variety of factors including, but not limited to:

—operating results that vary from our financial guidance or

the expectations of securities analysts and investors;

—the financial performance of the major end markets that

we target;

—the operating and securities price performance of

companies that investors consider to be comparable

to us;

—announcements of strategic developments, acquisitions

and other material events by us or our competitors;

—failure to meet or exceed financial estimates and

projections of the investment community or that we

provide to the public;

—issuance of new or updated research or reports by

securities analysts;

—changes in government regulations;

—financing or other corporate transactions;

—the loss of any of our key personnel;

—sales of our ordinary shares by us, our executive officers

and board members or our shareholders in the future;

—price and volume fluctuations in the overall stock market,

including as a result of trends in the economy as a

whole; and

—other events and factors, many of which are beyond

our control.

These and other market and industry factors may cause the

market price and demand for our ordinary shares to

fluctuate substantially, regardless of our actual operating

performance, which may limit or prevent investors from

readily selling their ordinary shares and may otherwise

negatively affect the liquidity of our ordinary shares. In the

past, when the market price of a stock has been volatile,

holders of that stock have sometimes instituted securities

class action litigation against the issuer. If any of the

holders of our ordinary shares were to bring such a lawsuit

against us, we could incur substantial costs defending the

lawsuit and the attention of our senior management would

be diverted from the operation of our business. Any

adverse determination in litigation could also subject us to

significant liabilities.

The requirements of being a U.S. public company,

including compliance with the reporting requirements of

the Securities Exchange Act of 1934, as amended (the

“Exchange Act”), and the requirements of the Sarbanes-

Oxley Act, may strain our resources, increase our costs

and distract management, and we may be unable to

comply with these requirements in a timely or

cost-effective manner.

As a new U.S. public company, we are required to comply

with new laws, regulations and requirements, certain

corporate governance provisions of Sarbanes-Oxley Act,

related regulations of the SEC and the requirements of the

NYSE, with which we were not required to comply as a

private company. Complying with these statutes,

regulations and requirements will occupy a significant

amount of our time and will significantly increase our costs

and expenses. We will need to: institute a more

comprehensive compliance function to test and conclude

on the sufficiency of our internal control over financial

reporting; comply with rules promulgated by the NYSE;

prepare and distribute periodic public reports; establish

new internal policies, such as those relating to insider

trading; and involve and retain to a greater degree outside

professionals in the above activities. At any time, we may

conclude that our internal controls, once tested, are not

operating as designed or that the system of internal

controls does not address all relevant financial statement

risks. In our second annual report on Form 20-F, our

independent registered public accounting firm must attest

to the effectiveness of our internal control over financial

reporting. Our independent registered public accounting

firm may issue a report that concludes it does not believe

our internal control over financial reporting is effective.

Compliance with Sarbanes-Oxley Act requirements may

strain our resources, increase our costs and distract

management; and we may be unable to comply with these

requirements in a timely or cost-effective manner.

As a new U.S. public company, we are subject to significant

regulatory oversight and reporting obligations under U.S.

federal securities laws and the continuous scrutiny of

securities analysts and investors. In addition, most members

of our management team have limited experience

managing a U.S. public company, interacting with U.S.

public company investors, and complying with the

increasingly complex laws pertaining to U.S. public

companies. Our management team may not successfully or

efficiently manage us as a U.S. public company. These new

obligations and constituents require significant attention

from our management team and could divert our

management team’s attention away from the day-to-day

management of our business, which could adversely affect

our business, results of operations and financial condition.

Further, we expect that, as a new U.S. public company,

being subject to these rules and regulations may make it

more difficult and more expensive for us to obtain director

and officer liability insurance and we may be required to

accept reduced policy limits and coverage or incur

substantially higher costs to obtain the same or similar

coverage. As a result, it may be more difficult for us to

attract and retain qualified individuals to serve on our board

of directors or as executive officers. We are currently

evaluating these rules, and we cannot predict or estimate

the amount of additional costs we may incur or the timing

of such costs.

We qualify as a foreign private issuer and, as a result, we

will not be subject to U.S. proxy rules and will be subject

to Exchange Act reporting obligations that, to some

extent, are more lenient and less frequent than those of a

U.S. domestic public company.

We report under the Exchange Act as a non-U.S. company

with foreign private issuer status. Because we qualify as a

foreign private issuer under the Exchange Act, we are

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	115

exempt from certain provisions of the Exchange Act that

are applicable to U.S. domestic public companies, including

(i) the sections of the Exchange Act regulating the

solicitation of proxies, consents or authorizations in respect

of a security registered under the Exchange Act; (ii) the

sections of the Exchange Act requiring insiders to file public

reports of their stock ownership and trading activities and

liability for insiders who profit from trades made in a short

period of time; and (iii) the rules under the Exchange Act

requiring the filing with the SEC of quarterly reports on

Form 10-Q containing unaudited financial and other

specified information, or current reports on Form 8-K, upon

the occurrence of specified significant events. In addition,

foreign private issuers are not required to file their annual

report on Form 20-F until 120 days after the end of each

fiscal year, while U.S. domestic issuers that are accelerated

filers are required to file their annual report on Form 10-K

within 75 days after the end of each fiscal year. Foreign

private issuers also are exempt from Regulation Fair

Disclosure, aimed at preventing issuers from making

selective disclosures of material information. As a result of

the above, you may not have the same protections afforded

to shareholders of companies that are not foreign private

issuers, some investors may find the ordinary shares less

attractive, and there may be a less active trading market for

the ordinary shares.

As a foreign private issuer, we are permitted to adopt

certain home country practices in relation to corporate

governance matters that differ significantly from the

corporate governance listing standards of the NYSE. These

practices may afford less protection to shareholders than

they would enjoy if we complied fully with the corporate

governance listing standards of the NYSE.

As a foreign private issuer listed on the NYSE, we are

subject to corporate governance listing standards.

However, NYSE rules permit a foreign private issuer like us

to follow the corporate governance practices of its home

country in lieu of certain NYSE corporate governance listing

standards, provided that we disclose which requirements

that we have not complied with in any year and confirm the

UK corporate governance practices we have complied with.

Certain corporate governance practices in the United

Kingdom, which is our home country, may differ

significantly from the NYSE corporate governance listing

standards. Although we voluntarily comply with the higher

corporate governance standards of the UK Corporate

Governance Code, we could include non-independent

directors as members of our nomination and remuneration

committee, and our independent directors would not

necessarily hold regularly scheduled meetings at which only

independent directors are present. We may in the future

elect to follow home country practices in the United

Kingdom with regard to other matters. Therefore, our

shareholders may be afforded less protection than they

otherwise would have under the NYSE corporate

governance listing standards applicable to U.S.

domestic issuers.

We may lose our foreign private issuer status, which would

then require us to comply with the Exchange Act’s

domestic reporting regime and cause us to incur

significant additional legal, accounting and other

expenses.

As a foreign private issuer, we are not required to comply

with all of the periodic disclosure and current reporting

requirements of the Exchange Act applicable to U.S.

domestic issuers. To the extent we no longer qualify as a

foreign private issuer as of June 30, 2024 (the end of our

second fiscal quarter in the fiscal year after this listing), we

would be required to comply with all of the periodic

disclosure and current reporting requirements of the

Exchange Act applicable to U.S. domestic issuers as of

July 1, 2024. In order to maintain our current status as a

foreign private issuer, either (a) a majority of our ordinary

shares must be either directly or indirectly owned of record

by non-residents of the United States or (b)(i) a majority of

our executive officers or directors cannot be U.S. citizens or

residents, (ii) more than 50% of our assets must be located

outside the United States and (iii) our business must be

administered principally outside the United States. If we

lose our status as a foreign private issuer, we would be

required to comply with the Exchange Act reporting and

other requirements applicable to U.S. domestic issuers,

including the requirement to prepare our financial

statements in accordance with U.S. generally accepted

accounting principles, which are more detailed and

extensive than the requirements for foreign private issuers.

We may also be required to make changes in our corporate

governance practices in accordance with various SEC and

NYSE rules. The regulatory and compliance costs to us

under U.S. securities laws if we are required to comply with

the reporting requirements applicable to a U.S. domestic

issuer may be significantly higher than the cost we would

incur as a foreign private issuer. As a result, we expect that

a loss of foreign private issuer status would increase our

legal and financial compliance costs and would make some

activities highly time consuming and costly. If we lose

foreign private issuer status and are unable to comply with

the reporting requirements applicable to a U.S. domestic

issuer by the applicable deadlines, we would not be in

compliance with applicable SEC rules or the rules of NYSE,

which could cause investors could lose confidence in our

public reports and could have a material adverse effect on

the trading price of our ordinary shares. We also expect

that if we were required to comply with the rules and

regulations applicable to U.S. domestic issuers, it would

make it more difficult and expensive for us to obtain

director and officer liability insurance, and we may be

required to accept reduced coverage or incur substantially

higher costs to obtain coverage. These rules and

regulations could also make it more difficult for us to

attract and retain qualified members of our board

of directors.

Failure to comply with requirements to design, implement

and maintain effective internal control over financial

reporting could have a material adverse effect on

our business.

As a UK public company traded on the Main Market of the

LSE, we are not required to evaluate our internal control

over financial reporting in a manner that meets the rules

and regulations of the SEC.

The process of designing and implementing effective

internal control over financial reporting is a continuous

effort that requires us to anticipate and react to changes in

our business and the economic and regulatory

environments and to expend significant resources to

maintain internal control over financial reporting that is

adequate to satisfy our reporting obligations as a U.S.

public company. If we are unable to establish or maintain

adequate internal control over financial reporting, it could

116	Diversified Energy Company PLC Annual Report and Form 20-F2023

cause us to fail to meet our reporting obligations on a

timely basis, result in material misstatements in our

consolidated financial statements and harm our results of

operations. In addition, we will be required, pursuant to the

rules and regulations of the SEC, to furnish a report by

management on the effectiveness of our internal control

over financial reporting in the second annual report

following the completion of this listing. This assessment will

need to include disclosure of any material weaknesses

identified by our management in our internal control over

financial reporting. Assessing the effectiveness of our

internal control over financial reporting will require

significant documentation, testing and possible

remediation. Testing and maintaining internal control over

financial reporting may divert our management’s attention

from other matters that are important to our business.

We may not be able to conclude on an annual basis that we

have effective internal control over financial reporting or

our independent registered public accounting firm may not

issue an unqualified opinion on the effectiveness of our

internal control over financial reporting. If either we are

unable to conclude that we have effective internal control

over financial reporting or our independent registered

public accounting firm is unable to issue an unqualified

opinion on the effectiveness of internal control over

financial reporting, investors could lose confidence in our

reported financial information, which could have a material

adverse effect on the trading price of our ordinary shares.

We will incur increased costs as a result of operating as a

public company in the United States, and our management

will be required to devote substantial time to new

compliance initiatives and corporate

governance practices.

As a U.S. public company, we will incur significant legal,

accounting and other expenses that we did not incur

previously. The Sarbanes-Oxley Act, the Dodd-Frank Wall

Street Reform and Consumer Protection Act, the listing

requirements of NYSE and other applicable securities rules

and regulations impose various requirements on non-U.S.

reporting public companies, including the establishment

and maintenance of disclosure controls and procedures,

internal control over financial reporting and corporate

governance practices. Our management and other

personnel will need to devote a substantial amount of time

to these compliance initiatives. Moreover, these rules and

regulations will increase our legal and financial compliance

costs and will make some activities more time consuming

and costly. For example, we expect that these rules and

regulations may increase the cost of our director and officer

liability insurance.

However, these rules and regulations are often subject to

varying interpretations, in many cases due to their lack of

specificity, and, as a result, their application in practice may

evolve over time as new guidance is provided by regulatory

and governing bodies. This could result in continuing

uncertainty regarding compliance matters and higher costs

necessitated by ongoing revisions to disclosure and

governance practices.

Because we may not pay any cash dividends on our

ordinary shares in the future, capital appreciation, if any,

may be your sole source of gains and you may never

receive a return on your investment.

Under current UK law, a company’s accumulated realized

profits, so far as not previously utilized by distribution or

capitalization, must exceed its accumulated realized losses

so far as not previously written off in a reduction or

reorganization of capital duly made (on a non-consolidated

basis), before dividends can be paid. Therefore, we must

have distributable profits before issuing a dividend.

Although we historically declared dividends on our ordinary

shares, in the future, our board of directors may decide, in

its discretion, not to declare and pay dividends based on a

number of factors, including our performance and financial

condition, cash requirements, future prospects, commodity

prices, the performance and dividend yield of our peers, in

addition to general economic conditions. Further, the

Group’s Credit Facility contains a restricted payment

covenant that limits its subsidiaries’ ability to make certain

payments with respect to their equity, based on the pro

forma effect thereof on certain financial ratios, which would

be the source of distributable profits from which we may

issue a dividend. Consequently, any historical declared

dividends are in no way a guide to potential future

dividends and capital appreciation, if any, on our ordinary

shares may be your sole source of gains.

There is no guarantee that we will continue to pay

dividends on our ordinary shares in the future.

Our ability and the Board’s decision to pay dividends is

dependent upon our performance and financial condition,

cash requirements, future prospects, commodity prices, the

performance and dividend yield of our peers, compliance

with the financial covenants and restricted payments

covenant in our Credit Facility, profits available for

distribution and other factors deemed to be relevant at the

time and on the continued health of the markets in which

we operate. Further, subsequent to our listing on the NYSE,

while our Board’s evaluation of our ability or need to pay

dividends will primarily remain a question of the foregoing

factors, it will also take into account the performance of our

ordinary shares, including relative to our peer group. There

can be no guarantee that we will continue to pay dividends

in the future on our ordinary shares.

The rights of our shareholders may differ from the rights

typically offered to shareholders of a U.S. corporation.

We are incorporated under UK law. The rights of holders of

ordinary shares are governed by UK law, including the

provisions of the UK Companies Act 2006 (the “Companies

Act 2006”), and by our Articles of Association. These rights

differ in certain respects from the rights of shareholders in

typical U.S. corporations. Refer to Memorandum and

Articles of Association in this Annual Report & Form 20-F

for a description of the principal differences between the

provisions of the Companies Act 2006 applicable to us and,

for example, the Delaware General Corporation Law

relating to shareholders’ rights and protections.

Claims of U.S. civil liabilities may not be enforceable

against us.

We are incorporated under the laws of the United Kingdom.

In addition, certain of our directors and officers reside

outside the United States. As a result, it may not be

possible for investors to effect service of process within the

United States upon such persons or to enforce judgments

obtained in U.S. courts against them or us, including

judgments predicated upon the civil liability provisions of

the U.S. federal securities laws.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	117

The United States and the United Kingdom do not currently

have a treaty providing for recognition and enforcement of

judgments (other than arbitration awards) in civil and

commercial matters. Consequently, a final judgment for

payment given by a court in the United States, whether or

not predicated solely upon U.S. securities laws, would not

automatically be recognized or enforceable in the United

Kingdom. In addition, uncertainty exists as to whether UK

courts would entertain original actions brought in the UK

against us or our directors or senior management

predicated upon the securities laws of the United States or

any state in the United States. Provided that certain

requirements are met, a final and conclusive monetary

judgment for a definite sum obtained against us in U.S.

courts (that is not a sum payable in respect of taxes or

similar charges or in respect of a fine or a penalty), would

be treated by the courts of the UK as a cause of action in

itself and sued upon as a debt at common law without any

retrial of the issue. Whether the relevant requirements are

met in respect of a judgment based upon the civil liability

provisions of the U.S. securities laws, including whether the

award of monetary damages under such laws would

constitute a penalty, is an issue for the court making such

decision. If a UK court gives judgment for the sum payable

under a U.S. judgment, the UK judgment will be enforceable

by methods generally available for this purpose. These

methods generally permit the UK court discretion to

prescribe the manner of enforcement.

As a result, U.S. investors may not be able to enforce

against us or our executive officers, board of directors or

certain experts named herein who are residents of the

United Kingdom or countries other than the United States

any judgments obtained in U.S. courts in civil and

commercial matters, including judgments under the U.S.

federal securities laws.

General Risks

Events of force majeure may limit our ability to operate

our business and could adversely affect our

operating results.

The weather, unforeseen events, or other events of force

majeure in the areas in which we operate could cause

disruptions or suspension of our operations. This

suspension could result from a direct impact to our

properties or result from an indirect impact by a disruption

or suspension of the operations of those upon whom we

rely for gathering and transportation. If disruption or

suspension were to persist for a long period, our results of

operations would be materially impacted.

If securities or industry analysts do not publish research,

or publish inaccurate or unfavorable research, about our

business, the price of our ordinary shares and our trading

volume could decline.

The trading market for our ordinary shares will depend in

part on the research and reports that securities or industry

analysts publish about us or our business. Securities and

industry analysts do not currently, and may never, publish

research on us. If no or too few securities or industry

analysts commence coverage on us, the trading price for

our ordinary shares would likely be negatively affected. In

the event securities or industry analysts initiate coverage, if

one or more of the analysts who cover us downgrade our

ordinary shares or publish inaccurate or unfavorable

research about our business, the price of our ordinary

shares would likely decline. If one or more of these analysts

cease coverage of us or fail to publish reports on us

regularly, demand for our ordinary shares could decrease,

which might cause the price of our ordinary shares and

trading volume to decline.

118	Diversified Energy Company PLC Annual Report and Form 20-F2023

Viability and Going Concern

In accordance with Provision 31 section 4 of the UK Corporate

Governance Code, and taking into account our current financial position

and principal risks for a period longer than the 12 months required by

the going concern statement, the Senior Leadership Team prepared a

viability analysis which was assessed by the Board for approval.

Strategy, Business Model and

Market Context

Our Strategy and Business Model are described in

their respective sections within this Annual Report & Form

20-F.

During 2023, we continued to grow and generate

significant operating cash flows from both our Appalachian

and Central Region assets. This growth allowed us to

generate an 8% increase in adjusted EBITDA year-over-

year. Our focus on acquiring assets from which we can

generate robust free cash flow in any price environment

remains central to our business model. We apply a

disciplined approach to valuing and acquiring assets,

protecting the associated cash flows with a proactive

hedge program, all while diligently working to enhance the

assets’ productivity and reduce expenses and emissions to

ensure we create a sustainable return to our shareholders.

During this time we have also used a significant portion of

our free cash flow to repay debt on our amortizing

borrowing structures and Credit Facility providing strong

additional evidence of our success.

2023 provided some unique market dynamics. We

experienced uncharacteristically low commodity prices as

well as significant inflationary pressures. We also saw an

aggressive rise in interest rates to combat inflation which

impacted the cost of capital for many. Our unique business

model leaves us well positioned for volatile markets,

however, and our consistent and reliable cash flows allowed

us to not only grow, but also to opportunistically layer on

additional derivative contracts at high pricing levels to

secure our cash flows at elevated levels in the future. The

importance of which has been recently evident as prices

have retreated substantially during the onset of 2024.

While periods of extreme volatility can make it challenging

for buyers and sellers to reach commercial terms, changing

commodity markets create added growth opportunity.

During higher commodity price environments companies

seek exit strategies to divest non-core assets creating the

necessary capital to drill and develop their core leasehold

positions. Conversely, during low commodity price

environments companies look to divest assets as they seek

additional liquidity to cover marginal well economics on

unhedged production. Thus, as markets cycle, it creates a

plethora of opportunities to build on our strategy of value-

accretive acquisitions.

Assessment Process and

Key Assumptions

Our financial outlook is assessed primarily through a

detailed annual business planning process and a more

general multi-year forecast. The Senior Leadership Team

provides the Board with a detailed overview as part of its

annual budget approval while providing regular updates at

each Board meeting throughout the year. The Board uses

this information, along with any other detail it requests, to

assess our current performance and longer-term outlook.

The outputs from the business planning process include a

set of key performance objectives, an assessment of our

primary risks, the anticipated operational outlook and a set

of financial forecasts that consider the sources of funding

available to DEC (the “Base Plan”).

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	119

Key assumptions, which underpin the annual business

planning process, include the forward price strip for each

commodity (natural gas, NGLs and oil), forecasted

operating cost and capital expenditure levels, production

profiles, and the availability of liquidity or additional

financing. We regularly produce cash flow projections,

which we sensitize for different scenarios including, but not

limited to, changes in commodity prices and production

rates from our wells. The Directors and Senior Leadership

Team closely monitor these forecast assumptions and

projections and seek to mitigate our operating and

liquidity risks.

Based on our financial scenario planning process, the

Directors and Senior Leadership Team believe that stress

testing forecast results over the Base Plan for a two-year

period through March 2026 forms a reasonable expectation

of our viability. At least annually, we perform our two-year

Base Plan forecast for our medium-term strategic planning

period. The two-year planning period has been reduced

from three years due to the loss of information value in the

third year primarily as a result of volatile commodity prices

and an incomplete hedge book. Therefore the Directors and

Senior Leadership Team endorse a two-year assessment

period to furnish the most pertinent and valuable data for

assessing the outlook of the business. The Directors and

Senior Leadership Team are confident that they

appropriately monitor and manage operational risks

effectively within the two-year Base Plan, and our scenario

planning is focused primarily on plausible changes in

external factors, providing a reasonable degree of

confidence.

Viability

The principal risks and uncertainties that affect the

Directors’ assessment of our viability in this period are:

—The effect of volatile natural gas prices on the business;

—Operational production performance of the producing

assets; and

—Operating cost levels and our ability to control costs.

The Base Plan incorporates key assumptions that reflect

these principal risks as follows:

—Projected operating cash flows are calculated using a

production profile which is consistent with current

operating results and decline rates;

—Assumes commodity prices are in line with the current

forward curve which considers basis differentials;

—Operating cost levels stay consistent with

historical trends which have been recently elevated due

to the inflationary environment;

—The financial impact of our current hedging contracts in

place, being approximately 83% and 76%, of total

production volumes hedged for the years ending

December 31, 2024 and 2025, respectively; and

—The scenario also includes the scheduled principal and

interest payments on our current debt arrangements.

To assess our viability, the Directors and Senior Leadership

Team considered various scenarios around the Base Plan

that primarily reflect a more severe, but plausible, downside

impact of the principal risks, both individually and in the

aggregate, as well as the additional capital requirements

that downside scenarios could place on us. Conservatively,

our viability statement considered the combined impact of

all three listed scenarios in:

Scenario 1: Cyclically low gas prices for a year (Henry Hub

prices of $1.50 per MMbtu before returning to strip pricing),

which have been historically observed in the market.

Scenario 2: Considered the impact of climate change by

assuming a 2 week period of lost production in our East

Texas/Louisiana region, which is susceptible to hurricanes,

due to a natural disaster (assumed to occur once in each

year of the assessment period).

Scenario 3: Considered the impact of climate change by

assuming a 2 week period of lost production in our

Appalachia region (assumption of lost production in 25% of

the total region), which is susceptible to flooding, due to a

natural disaster (assumed to occur once in each year of the

assessment period).

The Directors and Senior Leadership Team considered the

impact that these principal risks could, in certain

circumstances, have on our prospects within the

assessment period, and accordingly appraised the

opportunities to actively mitigate the risk of these severe,

but plausible, downside scenarios. Based on their

evaluation, the Directors and Senior Leadership Team have

a reasonable expectation that we will be able to continue to

operate and meet our liabilities as we mature over the two-

year period of their assessment.

Going Concern

In assessing our going concern status, we have taken

account of our financial position, anticipated future trading

performance, borrowings and other available credit

facilities, forecasted compliance with covenants on those

borrowings, and capital expenditure commitments and

plans. Our cash generation and liquidity remain adequate

and we believe we will be able to operate within

existing facilities.

The Directors are satisfied that our forecasts and

projections, that take into account reasonably possible

changes in trading performance, show that we have

adequate resources to continue in operational existence for

the next 12 months from the date of this Annual Report &

Form 20-F and that it is appropriate to adopt the going

concern basis in preparing our consolidated financial

statements for the year ended December 31, 2023.

The Strategic Report was approved by the Board of

Directors and signed on its behalf by:

David E. Johnson

Chairman of the Board

March 19, 2024

120	Diversified Energy Company PLC Annual Report and Form 20-F2023

gfx_corporate governance-breaker2.jpg

Corporate

Governance

122	The Chairman’s Governance Statement
128	Board of Directors
133	Directors’ Report
134	Principal Risks and Uncertainties
139	The Nomination & Governance<br><br>Committee’s Report
142	The Audit & Risk Committee’s Report
148	The Remuneration Committee’s Report
153	Remuneration at a Glance
169	The Sustainability & Safety Committee’s Report
Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	121
---	---	---	---	---
The Chairman’s Governance<br><br>Statement
---	---	---
Dear Shareholder,<br><br>As a Board we have been driving our governance standards towards meeting<br><br>best practice, and it has been my privilege to work with this Board which is<br><br>committed to maintaining high standards of corporate governance. As<br><br>Chairman of the Group, my role is to provide leadership, ensuring that the<br><br>Board performs its role effectively and has the capacity, ability, structure,<br><br>corporate governance systems and support to enable it to continue to do so.<br><br>This Governance section of this Annual Report & Form 20-F provides an<br><br>update on our Board and Corporate Governance Policy. It includes our<br><br>Corporate Governance Code compliance statements and the reports of the<br><br>Board committees, namely the Audit & Risk, Nomination & Governance,<br><br>Remuneration, and Sustainability & Safety Committees.<br><br>In these reports, we set out our governance structures and explain how we<br><br>have applied the UK Corporate Governance Code and additional changes<br><br>implemented due to the Group’s recent NYSE-listing.
		<br><br>David E. Johnson<br><br>Chairman of the Board<br><br>March 19, 2024
	“
	As a Board we have been<br><br>driving our governance<br><br>standards towards meeting<br><br>or exceeding best practice.

Governance Framework

The Group’s success is directly linked to sound and

effective governance and we remain committed to

achieving high standards in all we do. The Directors

recognize the importance of strong corporate governance

and have developed a corporate governance framework

and policies appropriate to the size of the Group.

As the Group grows, the Directors and Senior Leadership

Team continue to review and adjust our approach, make

ongoing improvements to the Group’s corporate

governance framework and policies and procedures as part

of building a successful and sustainable company. For

example, in connection with our NYSE-listing, the Group

refreshed its governance framework to incorporate NYSE

Rules and SEC Rules, as appropriate. Among other things,

this involved reviewing each Board committee charter and

implementing several new governance policies.

Good governance creates the opportunity for appropriate

decisions to be made by the right people at the right time

to support the delivery of our strategy and manage any

risks associated with delivery of that strategy.

Board Agenda and Activities

During the Year

The Board is responsible for the direction and overall

performance of the Group with an emphasis on policy and

strategy, financial results and major operational issues.

During the year, the matters reserved for the Board’s

decision have been reviewed and re-affirmed. Specific

matters for the Board’s consideration include:

—Approval of the Group’s strategic plan;

—Review of the performance of the Group’s strategy,

objectives, business plans and budgets;

—Review and assess the Group’s sustainability goals,

including the Group’s GHG emission intensity

reduction targets;

—Review and assess the Group’s health and safety metrics

and goals;

—Approval of the Group’s operating and capital

expenditure budgets and any material changes to them;

—Review of material changes to the Group’s corporate

structure and management and control structure;

—Review of changes to governance and business policies;

—Monitoring efforts related to community and stakeholder

engagement;

—Ensuring an effective system of internal control and

risk management;

—Ensure that appropriate succession planning procedures

are in-place;

—Approval of annual and interim reports and accounts,

and preliminary announcements of year-end results; and

—Review of the effectiveness of the Board and

its committees.

The Board delegates matters not reserved for the Board to

the Senior Leadership Team.

122	Diversified Energy Company PLC Annual Report and Form 20-F2023
BOARD OF DIRECTORS<br><br>Defines business strategy, assesses risks and monitors performance
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Remuneration Committee<br><br>Responsible for the Group’s<br><br>remuneration policy, and for<br><br>setting pay levels and bonuses<br><br>for senior management in line<br><br>with individual performance.<br><br>Ensures safety and<br><br>sustainability KPIs are included<br><br>in remuneration packages.	Sustainability &<br><br>Safety Committee<br><br>Monitors the Group’s social,<br><br>ethical, environmental and<br><br>safety performance, and<br><br>oversees all sustainable<br><br>development issues on<br><br>behalf of the Board.	Nomination & Governance<br><br>Committee<br><br>Ensures a balance of skills,<br><br>knowledge, independence,<br><br>experience and diversity<br><br>on the Board and its<br><br>committees. Monitors<br><br>the Group’s<br><br>governance structure.	Audit & Risk Committee<br><br>Supports the Board in<br><br>monitoring the integrity of<br><br>the Group’s financial<br><br>statements and reviews the<br><br>effectiveness of the Group’s<br><br>system of internal controls<br><br>and risk<br><br>management systems.		CEO<br><br>Takes ultimate responsibility for delivering on strategy, financial and operating performance.
---	---	---	---	---
Executive Vice<br><br>President of<br><br>Operations<br><br>Description of role<br><br>Coordinates operating<br><br>activities and<br><br>sustainability initiatives<br><br>to ensure transparency<br><br>and long-term value for<br><br>DEC’s stakeholders.	President & Chief<br><br>Financial Officer<br><br>Description of role<br><br>Manages the finance<br><br>and accounting<br><br>activities of the Group<br><br>and ensures that its<br><br>financial reports are<br><br>accurate and<br><br>completed in a<br><br>timely manner.<br><br>Oversees the Group’s<br><br>information technology<br><br>function to ensure<br><br>safety and soundness of<br><br>internal controls and<br><br>systems.	Chief Legal &<br><br>Risk Officer<br><br>Description of role<br><br>Responsible for legal and<br><br>compliance, government,<br><br>policy engagement,<br><br>community engagement<br><br>and land and mineral<br><br>owner engagement.	Executive Vice<br><br>President & Investment<br><br>Officer<br><br>Description of role<br><br>Responsible for<br><br>identifying and valuing<br><br>acquisition targets and for<br><br>developing and<br><br>implementing a<br><br>commodity marketing<br><br>strategy to maximize<br><br>commodity revenues.	Chief Human Resources<br><br>Officer<br><br>Description of role<br><br>Responsible for HR<br><br>function and employee<br><br>relations, policies,<br><br>practices and operations.
Responsibility<br><br>—Operations<br><br>—EHS<br><br>—Sustainability<br><br>—Regulatory	Responsibility<br><br>—Treasury<br><br>—Accounting &<br><br>Financial Reporting<br><br>—Investor Relations<br><br>—Information<br><br>Technology<br><br>—Sustainability<br><br>Reporting	Responsibility<br><br>—Legal & Compliance<br><br>—Land<br><br>—Policy Engagement<br><br>—Community<br><br>Relations	Responsibility<br><br>—Acquisitions<br><br>—Marketing	Responsibility<br><br>—Human Resource
Risk Management<br><br>Guidelines<br><br>—Employee Handbook<br><br>and Code of<br><br>Business Conduct &<br><br>Ethics<br><br>—EHS Policy & Field<br><br>Operating Guidelines<br><br>—Socio-Economic<br><br>Policy	Risk Management<br><br>Guidelines<br><br>—Employee Handbook<br><br>and Code of<br><br>Business Conduct &<br><br>Ethics<br><br>—Tax Policy<br><br>—Anti-Bribery &<br><br>Corruption Policies	Risk Management<br><br>Guidelines<br><br>—Employee Handbook<br><br>and Code of Business<br><br>Conduct & Ethics<br><br>—Anti-Bribery &<br><br>Corruption Policies<br><br>—Compliance Hotline &<br><br>Whistleblowing Policy<br><br>—Securities Dealing<br><br>Policy	Risk Management<br><br>Guidelines<br><br>—Employee Handbook<br><br>and Code of Business<br><br>Conduct & Ethics<br><br>—Anti-Bribery &<br><br>Corruption Policies	Risk Management<br><br>Guidelines<br><br>—Employee Handbook<br><br>and Code of Business<br><br>Conduct & Ethics<br><br>—Anti-Bribery &<br><br>Corruption Policies<br><br>—Compliance Hotline &<br><br>Whistleblowing Policy
Stakeholder<br><br>Engagement<br><br>Responsibility<br><br>—Communities<br><br>—Employees<br><br>—Joint Operating<br><br>Partners<br><br>—Suppliers	Stakeholder<br><br>Engagement<br><br>Responsibility<br><br>—Employees<br><br>—Rating Agencies<br><br>—Financial Institutions<br><br>—Debt & Equity<br><br>Investors	Stakeholder<br><br>Engagement<br><br>Responsibility<br><br>—Employees<br><br>—Industry Associations<br><br>—Communities<br><br>—Land & Mineral<br><br>Owners<br><br>—Government &<br><br>Regulators	Stakeholder<br><br>Engagement<br><br>Responsibility<br><br>—Customers	Stakeholder<br><br>Engagement<br><br>Responsibility<br><br>—Employees<br><br>—Communities
Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	123
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Board Effectiveness,

Composition and Independence

As of December 31, 2023, the Board was comprised of

seven Directors being the Group’s CEO, the Non-Executive

Chairman (who was independent upon appointment) and

five other Non-Executive Directors, all of whom were

deemed Independent Non-Executive Directors under the

UK Corporate Governance Code. As a foreign private issuer,

under the listing requirements and rules of the NYSE, we

are not required to have independent directors on our

Board, except that our audit committee is required to

consist fully of independent directors, subject to certain

phase-in schedules. Our Board has determined that six of

our seven Directors do not have a relationship that would

interfere with the exercise of independent judgment in

carrying out the responsibilities of a director and that each

of these directors is “independent” as that term is defined

under the rules of the NYSE.

On January 1, 2023, Kathryn Z. Klaber was appointed to the

Board as an Independent Non-Executive Director. She

currently serves on the Nomination & Governance

Committee and Sustainability & Safety Committee. This

appointment was the culmination of a search effort led by

the Nomination & Governance Committee, utilizing a

leading external Board-appointment vendor, Heidrick &

Struggles, which does not have any connection to the

Group. Ms. Klaber brings to the Board a range of

professional experience, including deep EHS, governance,

regulatory and risk management experience.

On September 15, 2023, Bradley G. Gray stepped down

from his role as an Executive Director of the Board

concurrent with his appointment as the Group’s President

and Chief Financial Officer.

The skills and experience of the Non-Executive Directors

are wide and varied and contribute to productive and

challenging discussions in the boardroom ensuring the

Board has appropriate independent oversight. For more

details on the skills, knowledge and experience of our

Board please see the Directors’ biographies in the Board of

Directors section within this Annual Report & Form 20-F.

With a Non-Executive Chairman, and, as of January 1, 2024,

four other Independent Non-Executive Directors, over half

of the Board is independent and the Audit & Risk and

Remuneration Committees are independent. As Mr. Thomas

has served on the Board for nine years as of January 1,

2024, the Board no longer considers him independent.

Female representation at the Board level has improved

from 29% in late-2019 to 43% as of December 31, 2023

(three out of seven Board members being female).

Recognizing the importance of workforce engagement,

Sandra M. Stash serves as the Director responsible for

workforce engagement as required under the UK Corporate

Governance Code. The Non-Executive Director Employee

Representative directly engages with employees and

provides a forum for feedback to management. These

discussions cover a variety of topics including the Group’s

culture, policies and actions. Ms. Stash has served as the

Non-Executive Director Employee Representative since

Further information on her role and the work

undertaken can be found in the Directors’ Report within

this Annual Report & Form 20-F.

The Board provides effective leadership and overall

management of the Group’s affairs. It approves the Group’s

strategy and investment plans and regularly reviews

operational and financial performance and risk

management matters. A schedule of matters reserved for

the Board is included in the previous section.

The Board and its committees hold regularly scheduled

meetings each year. Additional meetings are held when

necessary to consider matters of importance that cannot be

held over until the next scheduled meeting.

All Directors have access to the advice and services of the

Group’s solicitors and the Group’s Corporate Secretary,

who is responsible for ensuring that all Board procedures

are followed. Any Director may take independent

professional advice at the Group’s expense in the

furtherance of their duties.

In accordance with the UK Corporate Governance Code, the

Directors must stand for re-election annually. The Group’s

Articles of Association also require any new Director

appointed by the Board during the year to retire at the next

Annual General Meeting (“AGM”) and offer themselves

for re-election.

The Board delegates certain responsibilities to the Board

committees, listed below, which have clearly defined terms

of reference.

These terms of reference are reviewed annually to ensure

they remain fit for purpose and can be viewed on the

Group’s website at www.div.energy.

GENDER DIVERSITY	TENURE
3 of 7<br><br>Directors are Female	2 of 7<br><br>0-3 years
	2 of 7<br><br>4-6 years
	3 of 7<br><br>7+ years
124	Diversified Energy Company PLC Annual Report and Form 20-F2023
---	---

From left to right: Mr. David J. Turner, Jr.; Mr. Martin K. Thomas; Ms. Sylvia Kerrigan; Ms. Sandra M. Stash; Mr. Rusty Hutson, Jr.;

Mr. David E. Johnson; Ms. Kathryn Z. Klaber; Mr. Bradley G. Gray (served on the Board through September 15, 2023).

Board Committees

The Directors have established four Board committees: an

Audit & Risk Committee, Remuneration Committee,

Nomination & Governance Committee, and Sustainability &

Safety Committee. The members of these committees are

constituted in accordance with the requirements of the UK

Corporate Governance Code (the “Code”), as applicable.

The terms of reference of the committees have been

prepared in line with prevailing best practice, including the

provisions of the Code. A summary of the delegated duties

and responsibilities, terms of reference of the committees

and their activities for the year are presented in their

committee reports set out below.

Board Diversity

Diversity is a key component of the Group’s Board

composition, with emphasis placed not only on gender but

also on culture, nationality, experience and cognitive

diversity. The Board has recruited consistently over the last

few years to enhance its diversity and is focusing on a

period of stability before making further additions.

Although the Board does not currently have any ethnically

diverse members, it acknowledges the UK Listing Rules’

diversity targets, which the Group intends to continue to

closely examine and evaluate in 2024 in terms of Board

membership, additions, recruitment and retention.

The Board is pleased to report it has achieved two of the UK Listing Rules’ targets of (i) more than 40% female representation

on the Board, with 43% of the Board being female and (ii) a female holding a senior Board position, with Ms. Kerrigan serving

as the Senior Independent Director.

Diversity targets – Progress Update

Target	Progress
The Board aspires to meet and ultimately exceed the target<br><br>for at least 40% of Board positions to be held by females.	We are pleased to report that as at December 31, 2023, 43%<br><br>of our Board identified as female.
That at least one of the positions of Chair, CEO, CFO or<br><br>Senior Independent Director is held by a female.	As of December 31, 2023, our Senior Independent Director<br><br>position is held by a female.
That at least one member of the Board is from a minority<br><br>ethnic background.	While we have not achieved this target yet, we continually<br><br>aspire to increase diverse representation on our Board.
Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	125
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Board and Executive Management Diversity

Prepared in accordance with UK Listing Rule 9.8.6R(10) as of March 1, 2024:

GENDER IDENTITY OR SEX(a)

	Number of<br><br>Board members	Percentage of<br><br>the Board	Number of senior positions<br><br>on the Board (CEO, CFO,<br><br>SID and Chair)(a)	Number<br><br>in executive<br><br>management	Percentage<br><br>of executive<br><br>management
Male	4	57%	3	6	67%
Female	3	43%	1	3	33%
Other categories	0	0%	0	0	0%
Not specified/prefer not<br><br>to say	0	0%	0	0	0%

ETHNIC BACKGROUND

	Number of<br><br>Board members	Percentage of<br><br>the Board	Number of senior positions<br><br>on the Board (CEO, CFO,<br><br>SID and Chair)(a)	Number<br><br>in executive<br><br>management	Percentage<br><br>of executive<br><br>management
White British or other<br><br>White (including<br><br>minority-white groups)	7	100%	4	9	100%
Mixed/Multiple<br><br>Ethnic Groups	0	0%	0	0	0%
Asian/Asian British	0	0%	0	0	0%
Black/African/Caribbean/<br><br>Black British	0	0%	0	0	0%
Other ethnic group,<br><br>including Arab	0	0%	0	0	0%
Not specific/prefer not<br><br>to say	0	0%	0	0	0%

(a)The data reported on the basis of gender identity.

The Board continues to demonstrate diversity in a wider

sense, with Directors from the U.S. as well as the UK,

bringing a range of domestic and international experience

to the Board. The Board’s diverse range of experience and

expertise covers not only a wealth of experience of

operating in the natural gas and oil industry but also

extensive technical, operational, financial, legal and

environmental expertise. Further information on our

commitment to diversity at the Board and senior

management level is included in the Nomination&

Governance Committee Report within this Annual Report &

Form 20-F.

UK CORPORATE GOVERNANCE CODE

COMPLIANCE STATEMENT

The Directors support high standards of corporate

governance, and it is the policy of the Group to comply with

current best practice in UK corporate governance.

The UK Corporate Governance Code published in July 2018

by the Financial Reporting Council (“FRC”), as amended

from time to time, (the “Corporate Governance Code”)

recommends that: (i) the Chair of the Board of Directors

should meet the independence criteria set out in the

Corporate Governance Code on appointment; and (ii) the

Board should appoint one of the Independent Non-

Executive Directors to be the Senior Independent Director.

The Chair of the Board is David E. Johnson, who was

independent as of his appointment and whom the Group

continues to consider independent, and the Senior

Independent Director is Sylvia Kerrigan. The Board also

considers Sandra M. Stash, David J. Turner, Jr., Sylvia

Kerrigan and Kathryn Z. Klaber to meet the independence

criteria set out in the Corporate Governance Code.

Currently, the Board is of the opinion that as of the date of

this report it fully complies with the requirements of the

Corporate Governance Code other than as set out below.

The Corporate Governance Code recommends that the

chair of the Remuneration Committee should have served

on a remuneration committee previously for at least 12

months. When Sylvia Kerrigan was appointed as chair of

the Remuneration Committee, she had only served on the

committee for approximately 9 months. However, as of

March 17, 2023, Sylvia Kerrigan had served on the

Remuneration Committee for a full 12 months and, as a

result, the Group is currently in compliance in this respect.

Additionally, the Directors acknowledge the requirement to

implement a diversity policy that will be applicable to the

Group’s administrative, management and supervisory

bodies and the remuneration, audit and nomination

committees. The Group has yet to finalize such a policy at

this time but is committed to encouraging diversity and will

continue to evaluate and develop plans and policies in the

coming year that will promote diversity. Current disclosures

on the Group’s diversity achievements is included in the

section “Our Employees - Workforce Diversity” in the

Strategic Report and Nomination&Governance

Committee Report within this Annual Report & Form 20-F,

with the Board closely overseeing progress against

regulatory and stakeholder expectation.

OUR APPROACH TO GOVERNANCE

As of the date of this Annual Report & Form 20-F, our

Board is made up of seven Directors: one Executive

Director, chairman and five Non-Executive Directors (four

of whom are independent).

Alongside the continued focus on our business strategy, we

achieved significant milestones in 2023 in strengthening

core areas of the business. One such area of focus was

corporate governance, where we engaged external

consultants to advise on Board best practices, including

independence, composition and diversity.

126	Diversified Energy Company PLC Annual Report and Form 20-F2023

Key Governance Improvements During 2023

The Board recognizes the benefits of good governance

and is seeking to apply this in a meaningful way. DEC is a

rapidly evolving company that is in an expansion and

transition phase. Accordingly, the Board is acutely aware of

the need to rapidly and effectively integrate new businesses

into the reporting and governance framework of the Group,

as determined by the Board. It is recognized that the Board

has a key role in balancing the fundamental elements of

good governance, namely to deliver business growth

and build trust while maintaining a dynamic

management framework.

The Board appreciates the importance of good and

effective communication and remains in close contact with

its shareholders and other stakeholders.

The Board is actively engaged in the process of solidifying

its governance framework for its rapidly expanding

business. The Board concluded that overall compliance with

governance best practice has improved during the year

under review, with the following having been achieved:

—The Board re-affirmed several key governance policies

including the following: Securities Dealing Code,

Compliance Hotline and Whistleblowing Policy,

Anti-Bribery Policy, Socio-Economic Policy, Modern

Slavery Policy, EHS Policy, Climate Change Policy,

Employee Relations Policy, Human Rights Policy and

Business Partners Policy. Additionally, in 2023, the

Board reviewed and approved the following new

governance policies: Biodiversity Policy, Code of

Business Conduct & Ethics, Tax Policy and

Hedging Policy.

—The Board achieved further progression of the Group’s

overall corporate governance framework and practices,

taking into account evolving market best practices and

the Group’s NYSE-listing, including, among other things,

a review and update of the Group’s committee charters

and governance policies.

—The Audit & Risk Committee is fully independent and

continues to adopt best practice.

—The Remuneration Committee is also independent with 3

Non-Executive Directors and the Non-Executive

Chairman, and, together with a third-party consultant,

conducted a thorough review of the remuneration policy

and practices and undertook a consultation exercise with

the Group’s largest shareholders.

—Each committee completed a thorough charter

evaluation to identify gaps in coverage, relevance and

applicability as well as potential areas of improvement.

As a result of this exercise and with guidance from

external advisors, the committee charters for the

Nomination & Governance Committee, Audit & Risk

Committee and Remuneration Committee were updated

to reflect NYSE Rules and SEC Rules.

—Together with the executive management team, the

Chairman and the Nomination & Governance Committee

continued to formulate succession planning procedures

and plans around key-roles in management.

—The Board encouraged employee outreach and training

regarding the Group’s Compliance Hotline and

Whistleblowing Policy and was satisfied by measures

taken, including the placement of awareness posters with

hotline details in all major offices.

—The percentage of female Board members was increased

from 38% to 43%.

—Sylvia Kerrigan was appointed as Senior

Independent Director.

Corporate Governance Practices and Foreign

Private Issuer Status

Companies listed on the NYSE must comply with the

corporate governance standards provided under Section

303A of the NYSE Listed Company Manual. As a “foreign

private issuer,” as defined by the SEC, we are permitted to

follow home country corporate governance practices,

instead of certain corporate governance practices required

by the NYSE for U.S. domestic issuers, except that we are

required to comply with Sections 303A.06, 303A.11 and

303A.12(b) and (c) of the Listed Company Manual. Under

Section 303A.06, we must have an audit committee that

meets the independence requirements of Rule 10A-3 under

the Exchange Act. Under Section 303A.06, we must

disclose any significant ways in which our corporate

governance practices differ from those followed by

domestic companies under NYSE listing standards. Finally,

under Section 303A.12(b) and (c), we must promptly notify

the NYSE in writing after becoming aware of any non-

compliance with any applicable provisions of this Section

303A and must annually make a written affirmation to the

NYSE. Further, an LSE listed company must disclose in its

annual financial report a statement of how the listed

company has applied the principles set out in the UK

Corporate Governance Code, in a manner that would

enable shareholders to evaluate how the principles have

been applied, and a statement as to whether the listed

company has (a) complied throughout the accounting

period with all relevant provisions set out in the UK

Corporate Governance Code; or (b) not complied

throughout the accounting period with all relevant

provisions set out in the UK Corporate Governance Code

and if so, setting out: (i) those provisions, if any it has not

complied with; (ii) in the case of provisions whose

requirements are of a continuing nature, the period

within which, if any, it did not comply with some or all of

those provisions; and (iii) the company’s reasons for

non-compliance.

For the purposes of NYSE rules, so long as the Group

qualifies as a foreign private issuer, we are eligible to take

advantage of certain exemptions from NYSE corporate

governance requirements provided in the NYSE rules. We

are required to disclose the significant ways in which our

corporate governance practices differ from those that

apply to U.S. companies under NYSE listing standards.

Section 312.03 of the NYSE Rules requires that a listed

company obtain, in specified circumstances, (1) shareholder

approval to adopt or materially revise equity compensation

plans, as well as (2) shareholder approval prior to an

issuance (a) of more than 1% of its ordinary shares

(including derivative securities thereof) in either number or

voting power to related parties, (b) of more than 20% of its

outstanding ordinary shares (including derivative securities

thereof) in either number or voting power or (c) that would

result in a change of control. The Group intends to follow

home country law in determining whether shareholder

approval is required. Section 302 of the NYSE Rules also

requires that a listed company hold an annual shareholders’

meeting for holders of securities during each fiscal year. We

will follow home country law in determining whether and

when such shareholders’ meetings are required.

The Group may in the future decide to use other foreign

private issuer exemptions with respect to some or all of the

other requirements under the NYSE Rules. Following our

home country governance practices may provide less

protection than is accorded to investors under the NYSE

listing requirements applicable to domestic issuers. We

intend to take all actions necessary for us to maintain

compliance as a foreign private issuer under the applicable

corporate governance requirements of the Sarbanes-Oxley

Act of 2002, the rules adopted by the SEC and NYSE listing

standards. Because we are a foreign private issuer, our

directors and senior management are not subject to

shortswing profit and insider trading reporting obligations

under Section 16 of the Exchange Act. They will, however,

be subject to the obligations to report changes in share

ownership under Section 13 of the Exchange Act and

related SEC rules.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	127
Board of Directors<br><br>The Group has a commitment to strong governance, reporting and operating<br><br>standards. At the date of this report, the current Board consists of seven Directors:<br><br>including a Non-Executive Chair (who was independent upon appointment and<br><br>whom the Group continues to consider independent), a Non-Executive Vice-Chair,<br><br>an Executive Director, the Senior Independent Director, three additional<br><br>independent Non-Executive Directors.
---	---	---	---
	COMMITTEE MEMBERSHIPS
		Audit & Risk
		Nomination
		Remuneration
		Sustainability & Safety
	<br><br><br><br><br><br>		Chair			Committee Membership:<br><br>Remuneration Committee, Sustainability & Safety Committee<br><br>Experience:<br><br>Mr. Johnson has served on our board of directors since February 2017 and as our<br><br>Non-Executive Chairman of the Board since April 2019. He has worked at a number<br><br>of leading investment firms, as both an investment analyst and a manager, and more<br><br>recently in equity sales and investment management. Mr. Johnson currently serves on<br><br>the board of Chelverton Equity Partners, an AIM-listed holding company, where he<br><br>serves as a member of the Remuneration, Audit & Nomination committees.<br><br>Previously, Mr. Johnson was a consultant at Chelverton Asset Management from<br><br>August 2016 to February 2019. Prior to that, he worked as a fund manager for the<br><br>investment department of a large insurance company and then as Head of Sales and<br><br>Head of Equities at a London investment bank. Mr. Johnson earned a Bachelor of Arts<br><br>in Economics from the University of Reading.<br><br>Key Strengths:<br><br>Investment sector knowledge; providing strong leadership to the Board in<br><br>connection with the Board’s role of overseeing strategy and developing<br><br>stakeholder relations.<br><br>Current External Roles:<br><br>Chelverton Equity Partners (Director), an AIM-listed holding company.
---	---
David E. Johnson<br><br>Non-Executive Chairman,<br><br>Independent upon Appointment<br><br>Age 63<br><br>Appointed February 3, 2017 and<br><br>as Chair of the Board on April 30,<br><br>2019				Committee Membership:<br><br>None<br><br>Experience:<br><br>Mr. Hutson is our co-founder and has served as our Chief Executive Officer since<br><br>the founding of our predecessor entity in 2001. Mr. Hutson also serves on our<br><br>board of directors. Mr. Hutson is the fourth generation in his family to immerse<br><br>himself in the natural gas and oil industry, with family roots dating back to the<br><br>early 1900s. Mr. Hutson spent many summers of his youth working with his father<br><br>and grandfather in the oilfields of West Virginia. He graduated from Fairmont<br><br>State College (WV) with a degree in accounting. After college, Mr. Hutson spent<br><br>13 years steadily progressing into multiple leadership roles at well-known banking<br><br>institutions such as Bank One and Compass Bank. His final years in the banking<br><br>industry were spent as CFO of Compass Financial Services. Building upon his<br><br>experiences in the natural gas and oil industry, as well as the financial sector, Mr.<br><br>Hutson established Diversified Energy Company in 2001. After years of refining his<br><br>strategy, Mr. Hutson and his team took the Company public in 2017. He continues<br><br>to lead his team and expand the Group’s footprint. With a rapidly growing<br><br>portfolio, Mr. Hutson remains focused on operational excellence and creating<br><br>shareholder value.<br><br>Key Strengths:<br><br>Deep understanding and leadership in the natural gas and oil sector; strong track<br><br>record in developing and delivering results in line with strategy.<br><br>Current External Roles:<br><br>Vice Chairman of Board of Governors of Fairmont State University
---	---
Rusty Hutson, Jr.<br><br>Co-Founder and Chief Executive<br><br>Officer<br><br>Age 54<br><br>Appointed July 31, 2014
128	Diversified Energy Company PLC Annual Report and Form 20-F2023
---	---
	Committee Membership:<br><br>Nomination & Governance Committee<br><br>Experience:<br><br>Mr. Thomas has served on our board of directors since January 2015. He is a<br><br>consultant in the corporate team of the law firm Wedlake Bell LLP in London.<br><br>During a legal career of over 35 years, Mr. Thomas specialises in advising on IPOs<br><br>and secondary offerings of equity and debt on the London capital markets,<br><br>corporate governance requirements for UK listed companies, corporate finance<br><br>and M&A work (including cross-border transactions). Previously named one of The<br><br>Lawyer’s “UK Hot 100 Lawyers” and ranked by both Chambers and Partners and<br><br>Legal 500, Mr. Thomas has advised clients operating in a variety of sectors,<br><br>including natural gas and oil, renewable energy, natural resources and mining,<br><br>climate change, financial services and early stage technology. Mr. Thomas has also<br><br>held senior management positions including seven years as the European<br><br>Managing Partner of a global law firm headquartered in the United States.<br><br>Key Strengths:<br><br>Corporate law; advising on mergers and acquisitions; public offerings.<br><br>Current External Roles:<br><br>Wedlake Bell LLP (Consultant) and Jasper Consultants Limited (Director).
---	---
Martin K. Thomas<br><br>Non-Executive Vice Chair<br><br>Age 59<br><br>(independent through 12/31/23)<br><br>Appointed January 1, 2015				Committee Membership:<br><br>Sustainability & Safety Committee (Chair), Remuneration Committee,<br><br>Audit & Risk Committee<br><br>Experience:<br><br>Ms. Stash has served on our board of directors since October 2019. Ms. Stash<br><br>accumulated more than 35 years of international experience in the natural gas and<br><br>oil and hard rock and coal mining industries, beginning her career as one of the<br><br>first female drilling engineers in North America and most recently served as<br><br>Executive Vice President for Tullow Oil until her retirement on 1 April 2020. During<br><br>her time in these industries, Ms. Stash developed deep business and operations<br><br>experience across six continents and is recognized for her unique capabilities in<br><br>bridging the extractive sector to external stakeholders – in government, civil<br><br>society and at the community level. Her distinguished professional career also<br><br>included roles at ARCO, TNK-BP, BP, Anaconda and Talisman Energy, and<br><br>spanned top leadership positions in general management, commercial<br><br>negotiations, operations and engineering, supply chain management, government<br><br>and public affairs, sustainability and HSE. Ms. Stash holds a Directorship<br><br>Certification through the National Association of Corporate Directors and also<br><br>serves on the boards of Trans Mountain Company and Chaarat Gold.<br><br>Key Strengths:<br><br>Risk management and sustainability; operations and engineering;<br><br>employee engagement<br><br>Current External Roles:<br><br>Colorado School of Mines (Board of Governors member), Trans Mountain<br><br>Corporation, a Canadian Crown Corporation (Director) and Chaarat Gold Holdings<br><br>Limited (Director), an AIM-listed gold mining company.
---	---
Sandra M. Stash<br><br>Independent Non-Executive<br><br>Director and Non-Executive<br><br>Director Employee<br><br>Representative<br><br>Age 64<br><br>Appointed October 21, 2019
Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	129
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	Committee Membership:<br><br>Audit & Risk Committee (Chair), Remuneration Committee<br><br>Experience:<br><br>Mr. Turner has served on our board of directors since May 2019. Mr. Turner serves as<br><br>Chief Financial Officer of Regions Financial Corporation (“Regions”) and is a member<br><br>of the Regions Executive Leadership Team. Regions is an NYSE-listed S&P 500<br><br>banking group. Mr. Turner leads all of Regions’ finance operations, including financial<br><br>systems, investor relations, corporate treasury, corporate tax, management planning<br><br>and reporting, and accounting. Mr. Turner joined Regions in 2005 and led the Internal<br><br>Audit Division before being named Chief Financial Officer in 2010. His responsibilities<br><br>included overseeing various audits of the overall corporation, reporting to the Audit<br><br>and Risk Committee of the Board of Directors. Prior to joining Regions, Mr. Turner<br><br>served as an Audit Partner of KPMG LLP and previously served Arthur Andersen LLP<br><br>in a number of positions, culminating in Audit Partner. His primary focus was auditing<br><br>financial institutions. Mr. Turner earned a BS degree in accounting from the University<br><br>of Alabama and attended Tulane University in Louisiana.<br><br>Key Strengths:<br><br>Financial expert with recent and relevant experience; capital markets; financial<br><br>operations; audit experience.<br><br>Current External Roles:<br><br>Regions Financial Corporation (CFO) and Junior Achievement of Alabama, Inc.<br><br>(Board and Executive Committee).
---	---
David J. Turner, Jr.<br><br>Independent Non-Executive<br><br>Director<br><br>Age 60<br><br>Appointed May 27, 2019				Committee Membership:<br><br>Nomination & Governance Committee (Chair), Audit & Risk Committee, Sustainability<br><br>& Safety Committee<br><br>Experience:<br><br>Ms. Klaber has served on our board of directors since January 2023. Ms. Klaber has<br><br>more than 30 years of experience with a focus on energy development and EHS<br><br>compliance complements the Board’s collective experience. Ms. Klaber currently<br><br>serves as the Managing Director of The Klaber Group, which provides strategic<br><br>consulting services to businesses and organizations with a focus on energy<br><br>development in the United States and abroad. Prior to founding The Klaber Group,<br><br>Ms. Klaber launched and led the Marcellus Shale Coalition as its first CEO, growing<br><br>the organization to be the premier regional trade association for the natural gas<br><br>and oil industry in the Northeastern Unites States. As CEO from 2009 to 2013 of<br><br>the Marcellus Shale Coalition, Ms. Klaber worked closely with elected leaders,<br><br>regulators and member companies to advance the responsible development of the<br><br>Appalachian Basin. Ms. Klaber's other experience also includes serving as<br><br>the Executive Vice President for Competitiveness at the Allegheny Conference on<br><br>Community Development and Executive Director of the Pennsylvania Economy<br><br>League where her work focused on advancing key policy and regulatory matters.<br><br>Earlier in her career, Ms. Klaber accumulated significant experience in EHS strategy<br><br>and compliance with the international consulting firm Environmental Resource<br><br>Management. Ms. Klaber holds an undergraduate degree in environmental science<br><br>from Bucknell University and a Masters in Business Administration from<br><br>Carnegie Mellon University.<br><br>Key Strengths:<br><br>Regulatory compliance, energy specific sustainability programs; EHS processes<br><br>industry knowledge, risk management; governance<br><br>Current External Roles:<br><br>The Klaber Group (Managing Director); RLG International (Director) processes,<br><br>industry knowledge, risk management; governance
---	---
Kathryn Z. Klaber<br><br>Independent Non-Executive<br><br>Director<br><br>Age 58<br><br>Appointed January 1, 2023
130	Diversified Energy Company PLC Annual Report and Form 20-F2023
---	---
	Committee Membership:<br><br>Remuneration Committee (Chair), Nomination & Governance Committee<br><br>Experience:<br><br>Ms. Kerrigan has served on our board of directors since October 2021. Ms. Kerrigan<br><br>provides a wealth of experience in the energy, industrial and transportation sectors<br><br>where she has engaged in corporate responsibility and sustainability, merger and<br><br>acquisition, regulatory, risk management, cybersecurity and information privacy<br><br>matters. Ms. Kerrigan currently serves as the Chief Legal Officer for Occidental<br><br>Petroleum (NYSE: OXY). Prior to working at Occidental, Ms. Kerrigan served as the<br><br>Executive Director of the Kay Bailey Hutchinson Energy Center for Business, Law and<br><br>Policy at the University of Texas where she also earned a Doctor of Jurisprudence<br><br>degree and served in a number of roles with Marathon Oil Corporation over the<br><br>course of more than 20 years. In her time with Marathon Oil Corporation, she held a<br><br>number of roles overseeing public policy, legal and compliance,<br><br>corporate positioning and external communications before retiring in 2017 after eight<br><br>years as the Executive Vice President, General Counsel and Corporate Secretary.<br><br>Prior to working at Marathon, Ms. Kerrigan served in various domestic and<br><br>international corporate, government and legal roles, including an appointment to the<br><br>United Nations Security Council in Geneva, Switzerland. Ms. Kerrigan holds a NACD<br><br>Directorship Certification through the National Association of Corporate Directors.<br><br>Key Strengths:<br><br>Corporate law, governance, merger and acquisition, regulatory, risk management,<br><br>cybersecurity and information privacy matters, corporate responsibility<br><br>and sustainability.<br><br>Current External Roles:<br><br>Occidental Petroleum (Chief Legal Officer) and Team Industrial Services<br><br>(Lead Director).
---	---
Sylvia Kerrigan<br><br>Senior Independent<br><br>Non-Executive Director<br><br>Age 58<br><br>Appointed October 11, 2021			Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	131
---	---	---	---	---

Senior Management

	Mr. Gray has served as our President and Chief Financial Officer since September<br><br>2023, and prior to that served as Executive Vice President, Chief Operating Officer<br><br>since October 2016. Prior to joining us, Mr. Gray served as the Senior Vice President<br><br>and Chief Financial Officer for Royal Cup, Inc. from August 2014 to October 2016.<br><br>Prior to that, from 2006 to 2014, Mr. Gray served in various roles at The McPherson<br><br>Companies, Inc., most recently as Executive Vice President and Chief Financial<br><br>Officer from September 2006 to December 2013. Mr. Gray previously worked in<br><br>various financial and operational roles at Saks Incorporated from 1997 to 2006.<br><br>Mr. Gray has a B.S. degree in Accounting from the University of Alabama and earned<br><br>his CPA license (Alabama).<br><br>Key Strengths:<br><br>Corporate structure; operational processes and management; acquisition integration;<br><br>finance; strategic support to the CEO.<br><br>Current External Roles:<br><br>None
Bradley G. Gray<br><br>President and Chief<br><br>Financial Officer<br><br>Age 55		Mr. Sullivan has served as our Senior Executive Vice President, Chief Legal & Risk<br><br>Officer, and Corporate Secretary since September 2023, and prior to that served as<br><br>Executive Vice President, General Counsel and Corporate Secretary since 2019. Prior<br><br>to joining us, Mr. Sullivan worked with Greylock Energy, LLC (an ArcLight Capital<br><br>Partners portfolio company) and its predecessor, Energy Corporation of America,<br><br>from 2012 to 2017, most recently as Executive Vice President, General Counsel and<br><br>Corporate Secretary from 2017 to 2019. Prior to that, Mr. Sullivan served as counsel<br><br>for EQT Corporation from 2006 to 2012. He is a member of the leadership and board<br><br>of directors of several commerce, legal and industry groups, and has considerable<br><br>experience in corporate governance and reporting, corporate responsibility and<br><br>sustainability matters, complex commercial transactions, land/real estate,<br><br>acquisitions & divestitures, financing, government investigations and corporate<br><br>workouts and restructurings. Mr. Sullivan received a B.A. from the University of<br><br>Kentucky and a J.D. degree from the West Virginia University College of Law. He<br><br>holds licenses to practice law in several states, including Pennsylvania and West<br><br>Virginia.<br><br>Key Strengths:<br><br>Legal expert, mergers and acquisitions, land/real estate, regulatory compliance and<br><br>governance, risk management and strategic support to the CEO<br><br>Current External Roles:<br><br>None
---	---
Ben Sullivan<br><br>Senior Executive Vice President,<br><br>Chief Legal & Risk Officer, and<br><br>Corporate Secretary<br><br>Age 45
132	Diversified Energy Company PLC Annual Report and Form 20-F2023
---	---

Directors’ Report

The Directors present their report on the Group, together with

the audited Group Financial Statements, for the year ended

December 31, 2023.

Board of Directors

The Directors of the Group who were in office during the

year and up to the date of signing the financial

statements were:

—David E. Johnson - Non-Executive Chair (independent

upon appointment)

—Rusty Hutson, Jr. - Chief Executive Officer and

Executive Director

—Bradley G. Gray - President and Chief Financial Officer

and Executive Director (until September 15, 2023)

—Martin K. Thomas - Non-Executive Vice Chair

(independent from 1/1/2023 to 12/31/2023)

—David J. Turner, Jr. - Independent Non-

Executive Director

—Sandra M. Stash - Independent Non-Executive Director

—Sylvia Kerrigan - Senior Independent

Non-Executive Director

—Kathryn Z. Klaber - Independent Non-Executive Director

Incorporation and Listing

The Company was incorporated on July 31, 2014, and

completed the transfer to the Premium Listing Segment of

the Official List of the Financial Conduct Authority (“FCA”)

and admission to the Main Market of the LSE from AIM in

May 2020. The Company commenced trading on the New

York Stock Exchange (“NYSE”) on December 18, 2023.

Review of Business, Outlook

and Dividends

The Group is a natural gas, NGLs and oil producer and

midstream operator and is focused on acquiring and

operating mature producing wells with long lives and

low-decline profiles. The Group’s assets have historically

been located within the Appalachian Basin, but the Group

has acquired assets expanding its footprint into the Central

Region, consisting of the states of Louisiana, Texas and

Oklahoma. The Group is headquartered in Birmingham,

Alabama, U.S., and has field offices located throughout the

states in which it operates.

Details of the Group’s progress during the year and its

future prospects, including its intended dividend strategy,

are provided in the Chairman’s Statement and Strategic

Report within this Annual Report & Form 20-F.

Results

The Group’s reported statutory earnings for 2023 was

$760 million, or $16.07 per share, and when adjusted for

certain non-cash items, it reported adjusted EBITDA of

$543 million, or $11.51 per share. The Group’s adjusted

EBITDA for 2022 was $503 million, or $11.92 per share. For

more information on adjusted EBITDA refer to the APMs

section in Additional Information within this Annual Report

& Form 20-F.

Dividend Approach

The Board’s target has been to return free cash flow to

shareholders by way of dividend, on a quarterly basis, in

line with the strength and consistency of the Group’s

cash flows.

For the three months ended March 31, 2023, the Group paid

a dividend of $0.875 per share on September 29, 2023. For

the three months ended June 30, 2023, the Group paid a

dividend of $0.875 per share on December 29, 2023. For

the three months ended September 30, 2023, the Group

expects to pay a dividend of $0.875 per share on March 28,

For the three months ended December 31, 2023, the

Group expects to pay a dividend of $0.29 per share.

The Directors may further revise the Group’s approach to

dividends from time to time in line with the Group’s actual

results and financial position. The Board’s approach to its

dividend reflects the Group’s current and expected future

cash flow generation potential.

Disclosure of Information under

LR 9.8.4R

The information that fulfills the reporting requirements

under this rule can be found on the pages identified below.

Section	Topic	Location
(1)	Interest capitalized	Director’s Report, starting on<br><br>page 133
(2)	Publication of unaudited<br><br>financial information	Not applicable
(4)	Details of long-term<br><br>incentive schemes	Directors’ Remuneration<br><br>Report, starting on page 148
(5)	Waiver of emoluments by<br><br>a Director	Not applicable
(6)	Waiver of future<br><br>emoluments by a<br><br>Director	Not applicable
(7)	Non pre-emptive issues<br><br>of equity for cash	Share Capital, starting on<br><br>page 134
(8)	As item (7), in relation to<br><br>major subsidiary<br><br>undertakings	Not applicable
(9)	Parent participation in a<br><br>placing by a listed<br><br>subsidiary	Not applicable
(10)	Contracts of significance	Material Contracts, starting on<br><br>page 238
(11)	Provision of services by a<br><br>controlling shareholder	Not applicable
(12)	Shareholder waivers of<br><br>dividends	Not applicable
(13)	Shareholder waivers of<br><br>future dividends	Not applicable
(14)	Agreements with<br><br>controlling shareholders	Not applicable
Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	133
---	---	---	---	---

Directors’ Interest in Shares

The Directors’ beneficial interests in the Group’s share

capital, including family interests, on December 31, 2023 are

shown below. These interests are based on the issued share

capital at that time. As of March 1, 2024, there have been no

changes to the Directors’ interests. The Non-Executive

Directors will purchase shares after the release of this

Annual Report & Form 20-F pursuant to the Non-Executive

Director Share Purchase Program implemented in 2022.

Director	Appointed	Shares of £0.20	% of Issued Share Capital
Rusty Hutson, Jr.	July 31, 2014	1,207,645	2.54%
Bradley G. Gray(a)	October 24, 2016	146,947	0.31%
Martin K. Thomas	January 1, 2015	112,250	0.24%
David E. Johnson	February 3, 2017	23,750	0.05%
David J. Turner, Jr.	May 27, 2019	26,923	0.06%
Sandra M. Stash	October 21, 2019	2,234	0.00%
Kathryn Klaber	January 1, 2023	1,050	0.00%
Sylvia Kerrigan	October 11, 2021	1,341	0.00%
		1,522,140	3.20%

(a)Bradley G. Gray stepped down from the Board effective September 15, 2023.

Future Developments

The Directors continue to review and evaluate strategic

acquisition opportunities recommended by the Senior

Leadership Team, which align with the strategy and

requirements of the Group. Additional details are

disclosed in the Strategy section within this Annual Report

& Form 20-F.

Share Capital

As of December 31, 2023, the Group’s issued share capital

consisted of 47,923,726 shares with a par value of £0.20

each, with ~31% of record holders in the U.S. and ~57% of

record holders in the UK. The Group has only one class of

share and each share carries the right to one vote at the

Group’s AGM. No person has any special rights of control

over the Group’s share capital and all issued shares are fully

paid. There are no specific restrictions on the size of a

holding nor on the transfer of shares, which are both

governed by the general provisions of the Group’s Articles

of Association and prevailing legislation. The Directors are

not aware of any agreements between holders of the

Group’s shares that may result in restrictions on the transfer

of securities or on voting rights. The amount of interest

capitalized by the Group during the period under review is

immaterial.

The Group was authorized by shareholders at the 2023

AGM held on May 2, 2023 to purchase in the market up to

10% of its issued shares (excluding any treasury shares),

subject to certain conditions laid out in the authorizing

resolution. The standard authority is renewable annually;

the Directors will seek to renew this authority at the

upcoming AGM. Details of shares issued and repurchased

by the Group during the period are set out in Note 16 in the

Notes to the Group Financial Statements.

In February 2023, the Group placed 6,422,200 new shares

at $25.34 per share (£21.00) (stated on an adjusted basis

post the share consolidation) at a 5.2% discount to raise

gross proceeds of $163 million (approximately £135 million).

The new shares placed represented 13.4% of the Group’s

existing share capital at the date of placement. The Group

used the proceeds to fund the Tanos II transaction,

discussed in Note 5.

Employee Benefit Trust

An Employee Benefit Trust (“EBT”) was established in 2022

to purchase shares already in the market and is operated

through a third-party trustee. The objective of the EBT is to

benefit the Group’s employees and in particular, to provide

a mechanism to satisfy rights to shares arising on the

exercise or vesting of awards under the Group’s share-

based incentive plans and reduce dilution for shareholders.

As of March 1, 2024, the EBT holds 354,441 shares and has

distributed 435,072 shares under the Group’s share-based

incentive plans.

Financial Instruments

Details of the Group’s principal risks and uncertainties

relating to financial instruments are detailed below and in

Note 25 in the Notes to the Group Financial Statements.

Risk Management

Risk management is integral to all of the Group’s activities.

Each member of executive management is responsible for

continuously monitoring and managing risk within the

relevant business areas. Every material decision is preceded

by an evaluation of applicable business risks. Reports

on the Group’s risk exposure and reviews of its risk

management are regularly undertaken and presented to

the Board. Additional details regarding the Group’s risk

management can be found in Principal Risks and

Uncertainties in the Strategic Report within this Annual

Report & Form 20-F.

Securities Dealing Code

The Group adopted a Securities Dealing Code for share

dealings appropriate for a company listed on the Premium

Listing Segment of the Official List of the FCA and admitted

to the Main Market of the LSE and NYSE-listed company.

The code applies to the Directors, members of the Senior

Leadership Team and other relevant employees of the

Group and is monitored by the Group’s compliance-

focused employees.

134	Diversified Energy Company PLC Annual Report and Form 20-F2023

Other Corporate

Governance Policies

The Board reviewed and reaffirmed several key governance

policies in 2023, including the following:

—Compliance Hotline and Whistleblowing Policy - aims to

provide guidance as to how individuals may raise their

concerns and to ensure that they may do so confidently

and confidentially.

—Anti-Bribery & Corruption Policy - acknowledges the

Group’s commitment to right and ethical practices and

addresses bribery and corruption risk as a part of the

Group’s overall risk management strategy.

—Socio-Economic Policy - affirms the Group’s

commitment to being recognized as a leader in the field

of corporate responsibility and recognizes the added

value for our shareholders.

—Modern Slavery Policy - recognizes that modern slavery

is a significant global human rights issue and has many

forms including human trafficking, forced labor, child

labor, domestic servitude, people trafficking and

workplace abuse. The Group is committed to respecting

internationally recognized human rights, including

ensuring that we are in no way involved or associated

with the issue of forced or involuntary labor and that

modern slavery and human trafficking are not taking

place in any part of our business.

—EHS Policy - guides activities to protect employees,

contractors, the public and the environment.

—Climate Change Policy - recognizes that climate

change is a complex global issue and that the Group is

committed to playing its part in supporting the global

transition to a lower carbon world by reducing the

impact of the Group’s operations through

advancements and investments in our processes,

equipment and capabilities.

—Employee Relations Policy - acknowledges the value of

the Group’s employees and highlights the Group’s

commitments to promote employee safety, health and

well-being.

—Human Rights Policy - recognizes the Group’s

commitment and responsibility to ensure that human

rights are upheld in every of its business operations

and to promote human rights where it can make a

positive contribution.

—Business Partners Policy - provides the standards the

Group expects from its consultants, outsourced

providers, subcontractors, vendors and suppliers to

adhere to in their business activities with the Group.

The Board also reviewed and adopted the following new

governance policies in 2023:

—Biodiversity Policy - outlines the Group’s commitment to

promote a net positive impact on the environment and

its natural biodiversity.

—Code of Business Conduct and Ethics - provides the

standards the Group expects from its Directors, officers

and employees, including honest and ethical conduct,

compliance with applicable laws and prompt internal

reporting and accountability for adherence to the code.

—Tax Policy - outlines the Group’s tax objections and the

foundation of the Group’s tax approach.

These corporate governance policies can be viewed on the

Group’s website at www.div.energy.

Subsequent Events

Refer to Note 28 in the Notes to the Group

Financial Statements.

Director Attendance at Board and Committee Meetings

Directors are expected to attend and participate in all Board meetings and meetings of committees on which they serve and

are expected to be available for consultation with management as requested from time to time. Regular Board and committee

meetings are held at such times as the Board and committees, respectively, may determine. Special meetings may be called

upon appropriate notice at any time.

The following table shows the number of Board and committee meetings required to be held and actually held in 2023:

Type of Meeting	Number of Meetings<br><br>Required to be Held	Number of<br><br>Meetings Held
Board of Directors	0	11
Audit & Risk Committee	3	6
Nomination & Governance Committee	2	2
Remuneration Committee	2	7
Sustainability & Safety Committee	2	5
Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	135
---	---	---	---	---

Members of the Board attended Board and committee meetings (to the extent they were members of such committee in

2023) as summarized in the following table.

Director	Committee Seats<br><br>(during 2023)	Board	Audit & Risk<br><br>Committee	Nomination &<br><br>Governance<br><br>Committee	Safety &<br><br>Sustainability<br><br>Committee	Remuneration<br><br>Committee
Rusty Hutson, Jr.	None	11	0	0	0	0
Bradley G. Gray(a)	None	11	0	0	3	0
David E. Johnson		11	0	2	5	7
Martin K. Thomas(b)		11	4	2	0	0
Kathryn Z. Klaber(c)		11	2	2	5	0
Sandra M. Stash		11	6	0	5	7
David J. Turner, Jr.		11	6	-	0	7
Sylvia Kerrigan		9	0	2	0	7

(a)Left the Sustainability & Safety Committee concurrent with his departure from the Board on September 15, 2023, and thus was not required

to attend the last two committee meetings held in 2023.

(b)Left the Audit & Risk Committee on September 15, 2023 and thus was not required to attend the last two committee meetings held in 2023.

(c)Appointed to the Audit & Risk Committee on September 15, 2023 and thus was not required to attend the first four committee meetings held

in 2023.

DIRECTORS’ INDEMNITIES

As permitted by the Group’s Articles of Association, the

Directors have the benefit of an indemnity, which is a

qualifying third-party indemnity provision as defined by

Section 234 of the Companies Act 2006. The indemnity was

in force during the financial year and remains in force at the

date of this report. The Group also purchased and

maintained throughout the financial period Directors’ and

officers’ liability insurance in respect of itself and its

Directors. This confirmation is given and should be

interpreted in accordance with the provisions of Section 418

of the Companies Act 2006.

CONFLICT OF INTEREST

There are no potential conflicts of interest between any

duties owed by the Directors or members of the Senior

Leadership Team to the Group and their private interests

and/or other duties. In addition, there are no arrangements

or understandings with any of the shareholders of the

Group, customers, suppliers or others pursuant to which

any Director or member of the Senior Leadership Team was

selected to be a Director or Senior Manager. The Group

tests regularly to ensure awareness of any future potential

conflicts of interest and related party transactions.

Directors are required to declare any additional or changed

interests at the beginning of each Board meeting. In the

event a conflict should arise, the pertinent Director would

not take part in decision making related to the conflict.

Additionally, there are no family relationships among any of

our Directors or Senior Managers.

SUBSTANTIAL SHAREHOLDERS

As of March 1, 2024, the following shareholders hold greater than 3% of the Group’s issued shares with voting rights:

Shareholders(a)	Number of Shares	% of Issued Share Capital
NYSE Control Account	3,160,498	6.64%
Hargreaves Landsdown	2,842,924	5.98%
Interactive Investor	2,480,602	5.21%
Columbia Management Investment Advisers	2,394,439	5.03%
Vanguard Group	2,326,236	4.89%
JO Hambro Capital Management	2,281,524	4.80%
GLG Partners	2,230,257	4.69%
BlackRock	2,054,151	4.32%
M&G Investments	1,998,712	4.20%
abrdn	1,929,927	4.06%

(a)The Group derives the information from TR1 notifications, its third-party performed annual shareholder analysis to support its Foreign Private

Issuer status as a U.S. Corporation listed on the LSE, and from periodic third-party share register reports it receives.

136	Diversified Energy Company PLC Annual Report and Form 20-F2023

INDEPENDENT AUDITORS

The independent auditors, PricewaterhouseCoopers LLP

(“PwC”), have expressed their willingness to continue in

office as auditors and a resolution to reappoint

PricewaterhouseCoopers LLP will be proposed at the

forthcoming AGM.

CORPORATE GOVERNANCE STATEMENT

The Directors recognize the importance of sound corporate

governance and their associated report is set out in the

Chairman’s Governance Statement within this Annual

Report & Form 20-F. The Group reports against the UK

Corporate Governance Code.

As further described in the UK Corporate Governance

Code Compliance Statement provided within this Annual

Report & Form 20-F, the Group is currently in compliance

with the Corporate Governance Code other than as set on

page 126.

ENGAGEMENT WITH EMPLOYEES’

STATEMENT

The Group is exempted from some reporting requirements,

as it did not employ more than 250 employees in the UK

during the year under review. As of December 31, 2023, the

Group had 1,603 full-time employees, with 1,214 production

employees and 389 production support employees located

in ten states in the U.S.

In line with industry standards in the country of

employment, our employees maintain a range of

relationships with union groups. The Group has not

previously experienced labor-related work stoppages or

strikes and believe that our relations with union groups and

our employees are satisfactory.

As per Section 54(1) of the Modern Slavery Act 2015, our

Modern Slavery Policy is reviewed and approved by the

Board annually and published on ourwebsite at

www.div.energy. The statement covers the activities of the

Group and details policies, processes and actions we have

taken to ensure that slavery and human trafficking are not

taking place in our supply chains or any part of our

business. More information on our Modern Slavery Policy

can be found on our website at www.div.energy.

Pursuant to the Group’s Employee Handbook, the Group

will endeavour to make reasonable accommodation to the

known physical or mental limitations of qualified employees

with disabilities.

ENGAGEMENT WITH

STAKEHOLDERS’ STATEMENT

The Group adheres to best-in-class operating standards,

with a strong focus on EHS to ensure the safety of its

employees, local communities and the environment in

which the Group operates. This element of reporting is

discussed in the Section 172 Statement and Sustainability &

Safety Committee’s Report within this Annual Report &

Form 20-F. Furthermore, the Director designated to engage

with the workforce as required under the Corporate

Governance Code is currently Sandra M. Stash.

RELATIONS WITH SHAREHOLDERS

The Group aims to maintain its committed approach to

long-term sustainability, which, alongside its strict fiscal

discipline and stewardship, maximizes returns to its

shareholders. The Directors attach great importance to

maintaining good relationships with shareholders. Extensive

information about the Group’s activities is included in its

annual and interim reports and accounts and related

presentations. The Group also issues regular updates

to shareholders.

Persons possessing market sensitive information are

notified in accordance with the Market Abuse Regulation.

The Group is active in communicating with both its

institutional and private shareholders. The AGM provides an

opportunity for all shareholders to communicate with and

to question the Board on any aspect of the Group’s

activities. The Group maintains a corporate website at

www.div.energy where information on the Group is

regularly updated, including Annual and Interim Reports

and all announcements.

The Directors are available for communication with

shareholders and all shareholders have the opportunity, and

are encouraged, to attend and vote at the AGM of the

Group during which the Board will be available to discuss

issues affecting the Group. The Board stays informed of

shareholders’ views via regular meetings and other

communications they may have with shareholders.

Following the Group's 2023 AGM and as part of its

engagement related to items on which shareholders voted

at that meeting (including Resolution 14 concerning the

Directors’ Remuneration Report which passed with 62% of

votes in favor), the Group consulted and engaged with a

number of shareholders who voted against the resolutions

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	137

to better understand their concerns. The Directors are

thankful to the shareholders for sharing their views. They

understand that the negative voting results for Resolution

14 were principally related to the specific, one-off issue of

the grant price used for the 2020 LTIP awards and the

resulting remuneration outcomes. The dialogue with the

shareholders has highlighted that there remains strong

support for the Group's remuneration policy, which was

approved by shareholders at the 2022 AGM.

The Group's Remuneration Committee has discussed the

feedback received in detail with the Board and will

maintain dialogue with shareholders on matters related to

executive remuneration.

ENVIRONMENTAL INFORMATION

The Group adheres to best-in-class operating standards,

with a strong focus on EHS to ensure the safety of its

employees. There is extensive coverage of these issues

within the Group’s 2023 Sustainability Report which will be

available on its website at www.div.energy and in the

Sustainability & Safety Committee’s Report within this

Annual Report & Form 20-F.

DIVERSITY

We believe that an inclusive culture and diverse workforce

are healthy for a successful and sustainable business. We

value the rich diversity, skills, abilities and creativity that

people from different backgrounds and experiences bring

to the Group.

The Group is committed to encouraging diversity amongst

its workforce. Decisions related to recruitment selection,

development or promotion are based upon merit and ability

to adequately meet the requirements of the job, and are not

influenced by factors such as race, colour, religion, alienage

or national origin, ancestry, citizens, age, disability, gender,

marital status, pregnancy, veteran status, sexual orientation,

gender identity, genetic information, or any other

characteristic protected by applicable law. The Group aims

to ensure that applications for employment are given full

and fair consideration. We will continue to develop our

diversity metrics to promote equality of opportunity, pay

and reward on a non-discriminatory basis. The Group seeks

to ensure that all employees are given access to training,

development and career opportunities. In addition, every

effort is made to retrain and support employees who

become disabled while working within the Group.

CHARITABLE AND POLITICAL DONATIONS

The Group did not make any political donations or incur any

political expenditures to candidates or political campaigns

or candidates during the period.

During the year, the Group contributed nearly $2.1 million to

approximately 120 different community organizations.

Please refer to the Community Outreach and Engagement

section of this Annual Report & Form 20-F.

GOING CONCERN

The Directors have given careful consideration to the

appropriateness of the going concern basis in the

preparation of the financial statements. The validity of the

going concern concept is dependent on funding being

available for the working capital requirements of the Group

in order to finance the continuing development of its

existing projects for at least the next 12 months. Sufficient

funds are available in the short-term to fund the working

capital requirements of the Group. The Directors believe

that this will enable the Group to continue in operational

existence for the foreseeable future and to continue to

meet obligations as they fall due. Please refer to the

Viability and Going Concern section of this Annual Report

& Form 20-F for a summary of the Directors’ assessment.

ANNUAL GENERAL MEETING

The AGM of the Group will be held in London in mid-May of

Full details of these proposals will be set out in a

separate Notice of AGM sent to all shareholders.

Shareholders are invited to complete the proxy form

received either by post or vote electronically in CREST in

accordance with the Notes contained in the Notice of the

AGM. The Notice of the AGM and Proxy Form are available

on the Group’s website at www.div.energy.

ADDITIONAL DISCLOSURES

Supporting information that is relevant to the Directors’

report, which is incorporated by reference into this

report, can be found throughout this Annual Report & Form

20-F.

For considerations of post balance sheet events please

refer to Note 28 in the Notes to the Group Financial

Statements within this Annual Report & Form 20-F.

138	Diversified Energy Company PLC Annual Report and Form 20-F2023

The Nomination & Governance

Committee’s Report

Kathryn Z. Klaber<br><br>(58)<br><br>Independent<br><br>Non-Executive<br><br>Director<br><br>(Chair as of 9/15/23)<br><br>Strength:<br><br>Regulatory,<br><br>Sustainability<br><br>Independence from:<br><br>Management & Other<br><br>interests	Martin K. Thomas<br><br>(59)<br><br>Non-Executive<br><br>Director (Chair until<br><br>9/15/23; independent<br><br>from 1/1/23 to<br><br>12/31/23)<br><br>Strength:<br><br>Legal<br><br>Independence from:<br><br>Other interests	Sylvia Kerrigan<br><br>(58)<br><br>Senior Independent<br><br>Non-Executive<br><br>Director<br><br>Strength:<br><br>Industry, Governance<br><br>Independence from:<br><br>Management & Other<br><br>interests	David E. Johnson<br><br>(63)<br><br>Non-Executive<br><br>Director, Independent<br><br>upon appointment<br><br>(until 9/15/23)<br><br>Strength:<br><br>Finance<br><br>Independence from:<br><br>Management & Other<br><br>interests	David J.<br><br>Turner, Jr.<br><br>(60)<br><br>Independent<br><br>Non-Executive<br><br>Director<br><br>(committee member<br><br>until 1/1/23)<br><br>Strength:<br><br>Finance<br><br>Independence from:<br><br>Management &<br><br>Other interests

Key Objective

The Nomination & Governance Committee assists the Board

in (i) discharging its responsibilities related to reviewing its

structure, size and composition, (ii) recommending to the

Board any changes required for succession planning and

monitoring governance trends and best practices, and (iii)

identifying and nominating for approval Board candidates

to fill vacancies as and when they arise. The Nomination &

Governance Committee is responsible for leading the

process for appointments, ensuring plans are in place for

orderly succession for both the Board and senior

management positions, and overseeing the development of

a diverse pipeline for succession.

The committee is responsible for reviewing the results of

the Board’s Performance Review process and for making

recommendations to the Board concerning suitable

candidates for the role of Senior Independent Director, the

membership of the Board’s committees and the election or

re-election of Directors at each AGM.

The committee also oversees the Group’s governance

structure and monitors trends and compliance with

governance best practices.

Key Matters Discussed by the

Committee

During the past year the Nomination &

Governance Committee:

—Led the annual Board Performance Review process,

using Leadership Advisor Group as an outside resource,

over the course of the year, which included (i) an

evaluation of the structure, agendas and outcomes of

Board and Board committee meetings and (ii) a

comprehensive report and roundtable exercise with the

entire Board;

—Took steps with senior management to develop a

training regime for the entire Board for the 2023 year

and beyond, with training from internal personnel and

external resources on topical subjects such as

governance, oversight and Director responsibilities;

—Assessed the member composition of each Board

committee and recommended changes in connection

with Mr. Gray’s departure as an Executive Director of the

Board concurrent with his appointment as the Group’s

President and Chief Financial Officer with effect from

September 15, 2023 to ensure alignment with best

practices for Board and committee independence.

—Assisted with the transition of responsibilities in

connection with Ms. Klaber’s appointment as the

Nomination & Governance Committee Chair as of

September 15, 2023.

—Conducted (together with senior management) a

committee-by-committee assessment process to

evaluate and provide feedback to each committee chair;

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	139

—Worked with the Senior Independent Director and senior

management to facilitate the Senior Independent

Director’s review of the Chairman;

—Worked with the Chairman and senior management to

facilitate the review of the CEO;

—Worked with the Chief Human Resources Officer and

Chief Legal & Risk Officer to formulate succession

planning procedures and plans around key-roles

in management;

—Reviewed management’s stakeholder engagement

efforts and advised on strategy and best practices;

—Together with management, encouraged and maintained

oversight of the process to ensure appropriate and

proactive engagement with proxy firms;

—Monitored the gender and racial diversity statistics for

the Group’s application, interview and hiring process;

—Focused on the Group’s diversity objectives and

strategies and encouraged employee-wide diversity

training and other diversity initiatives;

—Reviewed and updated the committee’s Terms of

Reference to reflect best practices;

—Worked with management to ensure that filings

submitted to the SEC in connection with the Group’s

NYSE listing followed best recommended practices for

governance and oversight;

—Worked with external advisors and senior management

to analyze, assess and implement an enhanced

governance framework related to the Group’s NYSE

listing, including, among other things, a review and

update of the Group’s committee charters and

governance policies; and

—Encouraged and maintained oversight of employee

outreach and training regarding the Group’s Compliance

Hotline and Whistleblowing Policy and was satisfied by

measures taken, including the placement of awareness

posters with hotline details in all major offices.

Committee Effectiveness

The committee performed a critical analysis internal review

and evaluation on itself, as part of its annual self-review

process. No significant areas of concern were raised.

Membership

The committee is currently comprised of three Non-

Executive Directors, two of whom are considered

independent: Ms. Klaber (independent), the Nomination &

Governance Committee Chair, Mr. Thomas and Ms. Kerrigan

(independent). Ms. Klaber was appointed to the committee

as of January 1, 2023 and was appointed as the Nomination

& Governance Committee Chair as of September 15, 2023.

Additionally, Mr. Turner and Mr. Johnson stepped down

from the committee on January 1, 2023 and September 15,

2023, respectively. Benjamin Sullivan, Senior Executive

Vice President, Chief Legal & Risk Officer and Corporate

Secretary acts as Secretary to the committee.

Meetings and Attendance

The Nomination & Governance Committee met twice in

2023 and has met once thus far in 2024. At the end of each

committee meeting, the committee typically meets in

private executive session without management present to

ensure that points of common concern are identified and

that priorities for future attention by the committee are

agreed upon. The Chair of the committee keeps in close

contact with the Chief Executive Officer and Chief Legal &

Risk Officer between committee meetings. For committee

meeting attendance for each Director see the Directors’

Report within this Annual Report & Form 20-F.

Responsibilities and Terms

of Reference

The committee’s main duties are:

—Reviewing the structure, size and composition of the

Board (including the skills, knowledge, experience and

diversity of its members) and making recommendations

to the Board with regard to any changes required;

—Identifying and nominating, for Board approval,

candidates to fill Board vacancies as and when

they arise;

—Succession planning for Directors and other

senior managers;

—Reviewing annually the time commitment required of

Non-Executive Directors; and

—Overseeing the Group’s governance structure as well as

trends and compliance in governance best practices.

The committee has formal terms of reference which can be

viewed on the Group’s website at www.div.energy.

Corporate Responsibility in

Hiring

The committee and Board are proud of the progress made

to date on diversity within the Group, including achieving

the UK Listing Rules’ targets of (i) more than 40% female

representation on the Board, with 43% female Board

members, and (ii) a female holding a senior Board position,

with Ms. Kerrigan serving as the Senior Independent

Director.

The Group improved in gender balance in 2023. Evidencing

this improvement, the FTSE Women Leaders Review 2023

indicated Diversified ranks in 76th place among the FTSE

It also recognized 43% female representation at Board

level and 34% in the executive committee and direct

reports category (which is comprised of 35 females and 69

males). Within the energy sector, the Group is in 4th place.

The FTSE Women Leaders Review is an independent

framework supported by the Government that builds on the

excellent work of both the Hampton-Alexander and Davies

Reviews which ensures that talented women at the top of

business are recognized, promoted and rewarded.

The committee also acknowledges the UK Listing Rule

ethnic diversity targets, and the important role played by

the Parker Review, which the Group intends to continue to

closely examine and evaluate in 2024 in terms of Board

membership, additions, recruitment and retention.

The Group has a strong commitment to increasing its

gender and ethnic diversity and believes that a diverse and

engaged workforce and Board is an important goal. In

particular, the Group has taken steps to increase support

for and communication with underrepresented groups in

the communities in which it operates. It is the committee’s

hope that these efforts will increase interest in our industry

and assist in the development of an ethnically diverse

pipeline of candidates.

140	Diversified Energy Company PLC Annual Report and Form 20-F2023

Board Performance Review

Consistent with last year, the Nomination & Governance

Committee selected Leadership Advisor Group as an

independent consultant to assist with the Board

Performance Review process based on the positive

experience the committee had in prior years. Leadership

Advisor Group does not have any other connection with the

Group. The Board Performance Review focused on the

following topics, among other things:

—Strategy development and implementation;

—Risk awareness, monitoring and reporting;

—Cooperation with and evaluation process of the CEO and

Senior Leadership Team;

—Board composition and dynamics;

—Onboarding and induction programs;

—Meeting structure and operation;

—Meeting effectiveness;

—Shareholder and stakeholder relations;

—Committee, Senior Independent Director and Vice

Chairman value contribution; and

—Individual evaluation of the Chairman and all

Board members.

The Board Performance Review utilized a variety of

methods, including a bespoke, online questionnaire, analysis

of how time is spent during Board meetings, Board

composition mapping and Board composition

benchmarking. The evaluation, analysis and reporting took

place from May to November 2023 and confirmed that the

Board and its committee effectively perform their

respective roles. The review highlighted certain areas for

improvement such as restructuring meeting agendas to

enhance strategic discussions.

Kathryn Z. Klaber

Chair of the Nomination & Governance Committee

March 19, 2024

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	141

The Audit & Risk Committee’s Report

David J. Turner, Jr.<br><br>(60)<br><br>Independent Non-Executive<br><br>Director (Chair)<br><br>Strength:<br><br>Finance<br><br>Independence from:<br><br>Management & Other<br><br>interests	Sandra M. Stash<br><br>(64)<br><br>Independent Non-Executive<br><br>Director<br><br>Strength:<br><br>Industry<br><br>Independence from:<br><br>Management & Other<br><br>interests	Kathryn Z. Klaber<br><br>(58)<br><br>Independent Non-Executive<br><br>Director<br><br>(as of 9/15/23)<br><br>Strength:<br><br>Regulatory, Sustainability<br><br>Independence from:<br><br>Management &<br><br>Other interests	Martin K. Thomas<br><br>(59)<br><br>Non-Executive Director<br><br>(until 9/15/23;<br><br>Independent from 1/1/23<br><br>to 12/31/23)<br><br>Strength:<br><br>Legal<br><br>Independence from:<br><br>Other interests

This report covers the activities of the Audit & Risk

Committee in 2023 and in the period up to the approval of

the Annual Report & Form 20-F for the year ended

December 31, 2023.

Key Objective

The Audit & Risk Committee acts on behalf of the Board

and the shareholders to ensure the integrity of the Group’s

financial reporting. The committee’s main functions include,

among other things, reviewing and monitoring internal

financial control systems and risk management systems on

which the Group is reliant, reviewing annual and interim

accounts and auditors’ reports; making recommendations

to the Board in relation to the appointment and

remuneration of the Group’s external auditors; and

monitoring and reviewing annually the external auditors’

independence, objectivity, effectiveness and qualifications.

Key Matters Discussed by

the Committee

MAIN ACTIVITIES

—Reviewed and challenged interim and annual

financial reporting;

—Reviewed and approved the Group’s Hedging Policy;

—Reviewed the Group’s system of internal controls and

assessed its effectiveness;

—Engaged with management on the U.S. listing efforts,

including assessments of the related risks and post-

listing integration of the applicable NYSE Rules and SEC

Rules into the Group’s framework;

—Reviewed and assessed the Group’s approach to its asset

retirement obligations and overall liquidity;

—Reviewed and updated the committee’s Terms of

Reference to reflect best practices;

—Reviewed the Enterprise Risk Management control

strategy and function;

—Reviewed the Group’s procedures for detecting fraud,

prevention of bribery, and anti-money laundering

systems and controls;

—Reviewed the adequacy and security of processes for

employees and contractors to raise concerns

confidentially about possible wrongdoing in financial

reporting or other matters;

—Engaged with management regarding internal

investigations and compliance reviews;

—Oversaw the promotion of Joyce Collins to Vice

President of Internal Audit to further enhance the

Group’s internal audit function and engaged with Ms.

Collins during private executive sessions;

—Approved the external audit plan presented by PwC,

reviewed the effectiveness of the external audit and held

independent discussions with the lead audit partner as

well as private confirmatory meetings with members of

the PwC audit team; and

—Reviewed correspondence with the Financial Reporting

Council (the “FRC”) related to financial reporting.

INDEPENDENCE

—The committee regards independence of the External

Auditor as crucial in safeguarding the integrity of the

audit process and takes responsibility for ensuring an

effective three-way relationship between the committee,

the External Auditor and management. The committee

confirmed that the external auditors, PwC, remain

independent and that non-audit fees remain appropriate

and reasonable.

COMMITTEE EFFECTIVENESS

—The committee completed a critical review of its

operations and effectiveness during 2023 as part of its

annual self-review process. An independent third-party

conducted interviews with members of the committee to

obtain feedback. No significant areas of concern

were raised.

142	Diversified Energy Company PLC Annual Report and Form 20-F2023

AREAS OF FOCUS IN 2024

—Review the Group’s procedures in relation to maintaining

high standards across all ethics and compliance

matters;

—Ensure that all risks are appropriately identified,

prioritized, addressed, and are managed by the

respective risk owner; and

—Enhance our internal control procedures and financial

reporting mechanisms to ensure the Group’s ability to

achieve compliance with the Sarbanes-Oxley Act.

Membership

In line with the recommendations set by the UK Corporate

Governance Code, the Audit & Risk Committee is comprised

of three Independent Non-Executive Directors members:

David J. Turner, Jr., the Audit & Risk Committee Chair and

Financial Expert, Sandra M. Stash and Kathryn Z. Klaber.

Martin K. Thomas was appointed to the committee as a

Non-Executive Director as of January 1, 2023 and stepped

down from the committee on September 15, 2023

concurrent with Ms. Klaber’s appointment to the

committee. Benjamin Sullivan, Senior Executive Vice

President, Chief Legal & Risk Officer and Corporate

Secretary acts as Secretary to the committee.

The committee has recent and relevant financial experience

through the leadership of Mr. Turner, who is presently the

Chief Financial Officer at Regions Financial Corporation, a

publicly traded U.S. bank that is a member of the S&P 500

Index. Each committee member has been selected to

provide a wide range of financial and commercial expertise

necessary to fulfil the committee’s responsibilities.

No members of the Audit & Risk Committee have outside

connections with the Group’s external auditors.

Meetings and Attendance

The Audit & Risk Committee met six times in 2023 and has

met once thus far in 2024. Before each meeting, the

committee Chair met with the members of the finance team

to ensure there was a shared understanding of the key

issues to be discussed. Committee meetings are held in

advance of Board meetings to facilitate an effective and

timely reporting process. The committee Chair provided a

report to the Board following each meeting. For committee

meeting attendance for each Director see the Directors’

Report within this Annual Report & Form 20-F.

The committee regularly meets in private executive

sessions without management present, one with the Vice

President of Internal Audit and one with committee

members only, to ensure that points of common concern

are identified and that priorities for future attention by the

committee are agreed upon. It also conducts private

discussions with PwC as appropriate to ensure that the

committee has a clear and unobstructed line of

communication with its external auditors. The Chair of the

committee keeps in close contact with the Chief Legal &

Risk Officer, the Vice President of Internal Audit, the

President and Chief Financial Officer, Corporate Controller,

the finance team and the external auditors between

committee meetings.

Detailed below are the members of the Senior Leadership

Team who were invited to attend meetings as appropriate

during the calendar year. In addition, PwC attended certain

of the meetings by invitation as auditors to the Group.

—Rusty Hutson, Jr., Chief Executive Officer

—Bradley G. Gray, President and Chief Financial Officer

—Benjamin Sullivan, Senior Executive Vice President, Chief

Legal & Risk Officer, and Corporate Secretary

—Martin K. Thomas, Vice Chairman of the Board

—David E. Johnson, Chairman of the Board

—Michael Garrett, Senior Vice President of Accounting and

Corporate Controller

—Joyce Collins, Vice President of Internal Audit

—Representatives from PwC UK and PwC U.S.

Responsibilities and Terms

of Reference

The main responsibilities of the committee are:

—Reviewing accounting policies and the integrity and

content of the financial statements, including focusing on

significant judgments and estimates used in

the accounts;

—Monitoring disclosure controls and procedures and the

adequacy and effectiveness of the Group’s internal

financial controls and risk management systems;

—Monitoring the integrity of the financial statements of the

Group to assist the Board in ensuring that the Annual

Report & Form 20-F, when taken as a whole, are fair,

balanced and understandable;

—Considering the adequacy and scope of external audits

and overseeing the relationship with the external

auditors, including appraising the effectiveness of their

work prior to considering their reappointment and

considering whether to put the external audit contract

out to tender;

—Reviewing and approving the statements to be included

in annual reports on internal control and risk

management; and

—Reviewing and reporting on the significant issues

considered in relation to the financial statements and

how they are addressed.

In 2023, the Board undertook a formal assessment of the

Group’s primary financial service vendors, including its

external auditors’, PwC, independence and will continue to

do so as part of the annual audit process and prior to

making a recommendation to the Board for the auditors’ re-

appointment. This assessment in 2023 included:

—Reviewing PwC’s non-audit services provided to the

Group, including Audit Related Assurance Services

provided and the related fees;

—Reviewing PwC’s procedures for ensuring the

independence of the audit firm, and parties and staff

involved in the audit; and

—Obtaining confirmation from the auditors that, in their

professional judgment, they are independent.

The committee has formal terms of reference which can be

viewed on the Group’s website at www.div.energy.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	143

Actions Undertaken During

the Year

The key activities for the committee for the period under

review are set out below.

REVIEW OF THE FINANCIAL STATEMENTS

The Audit & Risk Committee monitored the integrity of the

annual financial statements and reviewed the significant

financial reporting matters and accounting policies and

disclosures in the financial reports. The external auditors

attended an Audit & Risk Committee meeting as part of the

full-year accounts approval process. The process included

the consideration of reports from the external auditors in

respect of the audit approach, and their findings in respect

of the audit of the 2023 financial statements.

“
The committee reviewed<br><br>the presentation of the Group’s<br><br>audited results for the year ended<br><br>December 31, 2023 and the unaudited<br><br>results for the six months ended June<br><br>30, 2023 to ensure they were fair,<br><br>balanced and understandable, when<br><br>taken as a whole.

FINANCIAL STATEMENTS AND

PRESENTATION OF RESULTS

The committee reviewed the presentation of the Group’s

audited results for the year ended December 31, 2023 and

the unaudited results for the six months ended June 30,

2023 to ensure they were fair, balanced and

understandable, when taken as a whole. The results were

assessed to ensure they provide sufficient information for

shareholders and other users of the accounts to assess the

Group’s position and performance, business model and

strategy. In conducting this review, particular focus was

given to the disclosures included in the basis of preparation

in Note 2 in the Notes to the Group Financial Statements in

relation to the Group’s funding position and the suitability

of the going concern assumption.

The committee reviewed the significant judgments

associated with the 2023 financial statements, including

“key audit matters”, and also reviewed the supporting

evidence for the Group’s going concern assessment.

The Board is required to provide its opinion on whether it

considers that the Group’s 2023 Annual Report & Form 20-

F, taken as a whole, are fair, balanced and understandable,

and provide the information necessary for shareholders to

assess the Group’s position and performance, business

model and strategy. The committee discussed the

preparation of the Group’s 2023 Annual Report & Form 20-

F with the Board. To support the Board in providing its

opinion, the committee considered the content and overall

cohesion and clarity of the Annual Report & Form 20-F and

assessed the quality of reporting through discussion with

management and the external auditors. This included

ensuring that feedback from stakeholders and other

individuals had been addressed and that examples of best

practice had carefully been considered in the context of the

Group. The process included considering each of the

elements (fair, balanced and understandable) on an

individual basis to ensure the Group’s reporting was

comprehensive in a clear and consistent way, and in

compliance with accounting standards and regulatory and

legal requirements and guidelines. The reviews carried out

by internal functions within the Group and independent

reviewers were undertaken with a view to ensuring that all

material matters have been correctly reflected in the

Group’s 2023 Annual Report & Form 20-F. In summary, the

committee is comfortable that the overall disclosures in the

2023 Annual Report & Form 20-F are fair, balanced and

understandable, when taken as a whole.

Attention continues to be paid to the presentation of the

results and financial position in the Annual Report & Form

20-F as well as APMs as indicators of performance. The

Board considers current treatment, which retains reference

to “adjusted EBITDA” and “EBITDA” to remain appropriate.

The Board regards these measures as an appropriate way

to present the underlying performance and development of

the business since it reflects the continuing investment

being made by the Group, particularly in relation to recent

and future acquisition activity. Additionally, this is how the

Board monitors the progress of the existing Group

businesses. Accordingly, the committee believes that

adjusted EBITDA provides useful information to investors

and the market generally in understanding and evaluating

the Group’s performance.

VALUATION OF NATURAL GAS AND OIL

PROPERTIES AND RELATED ASSETS

The committee considered the carrying value of the

Group’s assets and any potential impairment triggers. It

reviewed management’s recommendations, which were

also reviewed by the external auditors, including an

evaluation of the appropriateness of the identification of

cash-generating units and the assumptions applied in

determining asset carrying values. The committee was

satisfied with the assumptions and judgments applied by

management as well as the triggering event assessment,

which concluded that depressed commodity prices

represented an impairment trigger. Upon completing the

impairment analysis, the Group determined that the

carrying amounts of certain proved properties were not

recoverable from future cash flows, and therefore,

recognized an impairment charge of $42 million. Refer to

Note 10 in the Notes to the Group Financial Statements.

The committee also considered management’s

determination of the fair values of the acquisitions made

during 2023 and challenged management on such

determination. It reviewed management’s assumptions and

judgements, which were also reviewed by the external

auditors. The committee was satisfied with the fair

values calculated.

144	Diversified Energy Company PLC Annual Report and Form 20-F2023

VIABILITY AND GOING CONCERN

Management presented to the committee an assessment of

the Group’s future cash flow forecasts and profit

projections, available facilities, facility headroom, banking

covenants and the results of its sensitivity analysis. Detailed

discussions were held with management concerning the

matters outlined in the Viability and Going Concern section

in the Strategic Report and the basis of preparation in Note

2 in the Notes to the Group Financial Statements within this

Annual Report & Form 20-F. The committee discussed the

assessment with management and was satisfied that the

going concern basis of preparation, including the change in

the viability period, continues to be appropriate for the

Group and advised the Board accordingly. In addition, the

committee reviewed the going concern assumptions with

PwC, including PwC’s review of management’s assessment

of the Group’s ability to continue as a going concern. The

financial statements of Diversified Energy Company PLC

have been prepared on a going concern basis.

The committee reviewed and challenged management’s

process and assessment of viability by considering various

scenarios on forecasted cash flows, including a base case

and downside scenario analysis which reflects the more

severe impact of the principal risks and includes future

climate change impacts. In reaching its view, the committee

also considered: (i) financial forecasts and the appropriate

period for the viability outlook; (ii) the Group’s financing

facilities including covenant tests and future funding plans,

(iii) the updated assessment period of 2 years and (iv) the

external auditors’ findings and conclusions on this matter.

The committee also considered the adequacy and accuracy

of the disclosures in the 2023 Annual Report & Form 20-F in

respect of the Group’s future viability. Following this

thorough assessment, the committee considered the extent

of the assessment made by management to be appropriate

and recommended the viability statement, including the

change to the viability period, and related disclosures (for

inclusion in the 2023 Annual Report & Form 20-F) for

approval by the Board.

RISK MANAGEMENT

Effective risk management and controls are key to

executing the Group’s business strategy and objectives.

Risk management and control processes are designed to

identify, assess, mitigate and monitor significant risks, and

can only provide reasonable and not absolute assurance

that the Group will be successful in delivering its objectives.

The Board is responsible for the oversight of how the

Group’s strategic, operational, financial, human and

personnel, legal and regulatory risks are managed and for

assessing the effectiveness of the risk management and

internal control framework.

Embedding the enterprise risk management framework and

assessing management’s response to the Group’s material

risks continues to be an area of focus with the committee

providing challenge and direction as appropriate. During

2023, the committee continued to consider the process for

identifying and managing risk within the business and

assisted the Board in relation to compliance with the UK

Corporate Governance Code and FRC guidance.

Recognizing the evolving nature of the risk landscape, due

to the increasing pace of change in the industry, the

continued impact of the macroeconomic environment and

global instability, more than ever, the Group needs to

manage risks smartly to achieve its vision, deliver strategy

and create sustainable shareholder value.

The Group maintains a risk management program to

identify principal risks and risk mitigation activities that

includes reviewing the impact, likelihood, velocity,

mitigation measures and residual risk. A description of the

Group’s risk management program, principal risks, and risk

mitigation activities is provided in the Principal Risks and

Uncertaintiessection in the Strategic Report within this

Annual Report & Form 20-F.

In addition to the risks that management identifies through

the ongoing processes of reporting and performance

analysis, the Audit & Risk Committee has additional risk

identification processes, which include:

—A risk and control process for identifying, evaluating and

managing major business risks;

—External experts, who comment on controls to manage

identified risks; and

—A confidential and externally managed whistleblowing

hotline and a compliance reporting website for

employees to contact the Chair of the Audit & Risk

Committee, Chief Legal & Risk Officer and Head of

Human Resources in confidence.

INTERNAL AUDIT

The work performed by the Internal Audit team in 2023 and

the results of testing the risk framework continue to

support a favorable outcome on the adequacy and

effectiveness of the Group’s internal controls. The Internal

Audit team leveraged both audit work previously

completed and knowledge of the Group to arrive at that

conclusion. Internal testing was performed (and continues

to take place) on the key controls identified throughout the

business processes that impact the financial statements.

There was additional focus around the completeness and

accuracy element of support, updating process

documentation, and completing walkthroughs of the

processes with the Group’s external auditors.

At each committee meeting, an update on Internal Audit is

provided covering an overview of the work undertaken in

the period, actions arising from audits conducted, the

tracking of remedial actions, and progress against the

Internal Audit Plan. The team continues to be led by the

Vice President of Internal Audit who has significant prior

experience in leading natural gas and oil industry internal

audits and has a straight line of communication available

with the Audit & Risk Committee. The team also consists of

a highly experienced audit manager as well as two

additional staff auditors, all of whom have years of industry

experience. Collectively, this team works under the

oversight of the Corporate Controller and reports to the

Chief Financial Officer who is responsible for the Group’s

ERM and internal controls framework.

The Group’s internal controls over financial reporting and

the preparation of consolidated financial information

include policies and procedures that provide reasonable

assurance that transactions have been recorded and

presented accurately. Management regularly conducts

reviews of the internal controls in place in order to provide

a sufficient level of assurance over the reliability of the

financial statements.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	145

INTERNAL CONTROL SYSTEMS

The committee is responsible for overseeing management’s

establishment and maintenance of the Group’s system of

internal control and reviewing its effectiveness. Internal

control systems are designed to meet the particular needs

of the Group and the particular risks to which it is exposed.

The Board has reviewed the Group’s risk management and

control systems noting they were in place for the year

under review and up to the date of approval of the 2023

Annual Report & Form 20-F and believes that the controls

are satisfactory, given the nature and size of the Group.

The internal controls, which provide assurance to the Audit

& Risk Committee of effective and efficient operations,

internal financial controls and compliance with laws and

regulations include:

—A formal authorization process for investments;

—An organizational structure where authorities and

responsibilities for financial management and the

maintenance of financial controls are clearly defined;

—Anti-bribery and corruption policies and procedures and

a dedicated telephone number and website designed to

address the specific areas of corruption risk faced by the

Group; and

—A comprehensive financial review cycle where annual

budgets are formally approved by the Board and

monthly variances are reviewed against detailed financial

and operating plans.

The committee considered the inherent risk of

management override of internal controls as defined by

Auditing Standards and performed the following actions

during 2023:

—Reviewed management’s report on the Group’s fraud

prevention framework and the key controls in place in its

operations designed to prevent and detect fraud, as well

as future plans for enhancement of the relevant controls;

—Discussed the on-going assessment of application

controls and the impact on the Group’s fraud framework.

Once complete, this assessment will help identify the

information technology controls that already exist within

certain financial processes and provide further

confidence in the strength of fraud prevention;

—Discussed the steps management had taken, including

designing a fraud detection process for the specific fraud

risks identified;

—Financial processes identified with critical fraud risk

potential were reviewed at an elevated level and controls

adjusted accordingly per discussion with management;

—Assessed the measures in place, including segregation of

duties ensuring independent review, to mitigate against

the risk of management override of controls;

—Discussed PwC’s audit procedures, including the results

of their conclusions relating to the fraud risk in revenue

recognition with a particular focus on ensuring the

existence of revenue transactions;

—The Committee challenged management on the

robustness of the controls; and

—Reviewed the overall robustness of the control

environment, including consideration of the Group’s

whistleblowing and compliance arrangements.

The committee agreed with management’s assessment that

the overall control framework remained effective and, with

a focus on high-risk and material areas, additional controls

introduced had mitigated risk.

SAFEGUARDS AND EFFECTIVENESS OF THE

EXTERNAL AUDITORS

The committee is responsible for oversight and for

managing the relationship with our external auditors. The

committee recognizes the importance of safeguarding the

independence and objectivity of the external auditors. The

following safeguards are in place to ensure that the

independence of the auditors is not compromised.

—The Audit & Risk Committee carries out an annual review

of the external auditors regarding their independence

from the Group and that they are adequately resourced

and technically capable to deliver an objective audit to

shareholders. Based on this review, the Audit & Risk

Committee recommends to the Board the continuation,

or removal and replacement, of the external auditors;

—The external auditors may only provide non-audit

services permitted by the FRC’s Revised Ethical

Standard 2019 (the “Ethical Standard”) which was issued

in December 2019. These services include audit-related

services such as regulatory and statutory reporting as

well as other items relating to shareholder and

other circulars;

—The committee reviews all fees paid for audit and audit-

related services on a regular basis to assess the

reasonableness of fees, value of delivery and any

independence issues that may have arisen or may

potentially arise in the future;

—The external auditors report to the Directors and the

Audit & Risk Committee regarding their independence in

accordance with relevant standards;

—Non-audit services carried out by the external auditors

are limited to work that is closely related to the annual

audit or where the work is of such a nature that a

detailed understanding of the business is beneficial, and

utilizes subject matter experts not conducting

audit services;

—The committee monitors costs for non-audit services in

absolute terms and in the context of the audit fee for the

year to ensure that the potential to affect the

independence and objectivity of the auditors does not

arise. During 2023, non-audit services included work

around the Group’s half-year review and acquisitions

which did not affect the independence and objectivity of

the auditors; and

—Information related to audit fees for 2023 is

detailed in Note 7 in the Notes to the Group

Financial Statements.

This is the external auditor’s fourth year as the Group’s

external auditor following a formal tender process during

2020 and subsequent appointment at the 2020 AGM.

Tim McAllister has fulfilled the role of lead audit partner for

a fourth year.

The committee confirms that the Group has complied with

the requirements of the Statutory Audit Services for Large

Companies Market Investigation (Mandatory Use of

Competitive Tender Processes and Audit Committee

Responsibilities) Order 2014 for the financial year

under review.

146	Diversified Energy Company PLC Annual Report and Form 20-F2023

The committee is cognizant of the fact that assessing

external audit quality is a key responsibility within its remit

which stakeholders look to the committee to discharge. The

Audit & Risk Committee continually monitors the

effectiveness of the external audit. To comply with this

requirement, the committee reviewed and commented on

PwC’s detailed audit plans and strategy, including the

intended scope of the audit, identification of significant and

elevated audit risks, the level of materiality proposed and

the principles of PwC’s centrally directed audit approach.

Many elements of the audit plan approach remained

consistent with the 2022 audit, and the committee

welcomed the plan to enhance the focus on utilizing

data‑enabled auditing approaches to maximize efficiencies

and insight from the auditors’ testing. Following discussion

and challenge, the committee agreed on the methodology

adopted for determining materiality and the scope of

the audit.

It then considered progress during the year by assessing

the major findings of its work, the perceptiveness of

observations, the implementation of recommendations and

the management of feedback. At the request of the Board,

the committee also monitors the integrity of the financial

information in the Annual Report & Form 20-F, half-year

results statements, and the significant financial reporting

judgments contained in them. Further details of the

committee’s procedures to review the effectiveness of the

Group’s systems of internal control during the year can be

found in the section on effective risk management and

internal control above.

The committee recognizes that all financial statements

include estimates and judgments by management. The key

audit areas are agreed upon with management and the

external auditors as part of the year-end audit planning

process. This includes an assessment by management of

the significant areas requiring management judgment and

the committee challenging management’s judgments. These

areas are reviewed with the auditors to ensure that

appropriate levels of audit work are completed, and the

committee reviews the results of this work. The numerous

interactions with the auditor provided the committee with

an insight into the quality of the audit process and the audit

leadership team, and with the opportunity to assess the

auditor’s challenge of management’s views.

ASSURANCE MEASURES

On behalf of the Board, the Audit & Risk Committee

examines the effectiveness of:

—The systems of internal control, primarily through

reviews of the financial controls for financial reporting of

the annual, preliminary and half-yearly

financial statements;

—The management of risk by reviewing evidence of risk

assessment and management; and

—Any action taken to manage critical risks or to remedy

any control failings or weaknesses identified, ensuring

these are managed through to closure.

Where appropriate, the Audit & Risk Committee ensures

that necessary actions have or are being taken to remedy

or mitigate significant failings or weaknesses identified

during the year either from internal review or from

recommendations raised by the external auditors. In 2023,

the committee did not identify any significant failings or

weaknesses in the system of risk management and internal

control. The Group’s internal controls over the financial

reporting and consolidation processes are designed under

the supervision of the Group’s President and Chief Financial

Officer to provide reasonable assurance regarding the

reliability of financial reporting and the preparation and fair

presentation of the Group’s published financial statements

for external reporting purposes, in accordance with IFRS as

issued by the International Accounting Standards Board.

Because of its inherent limitations, internal control over

financial reporting cannot provide absolute assurance and

may not prevent or detect all misstatements whether

caused by error or fraud. The Group’s internal controls over

financial reporting and the preparation of consolidated

financial information include policies and procedures that

provide reasonable assurance that transactions have been

recorded and presented accurately.

Management regularly conducts reviews of the internal

controls in place in respect of the processes of preparing

consolidated financial information and financial reporting.

During the year, there has been a significant investment in

resources, processes and personnel relating to the internal

controls of these processes to reflect the growth of the

Group. This is in order to provide a sufficient level of

assurance over the reliability of the financial statements.

OTHER FINANCIAL REPORTING MATTERS

In October 2023, the Group received a letter from the FRC

in relation to its regular review and assessment of the

quality of corporate reporting. The letter focused on the

2022 Annual Report with inquiries on the following

main areas:

—The nature of the restrictions placed on the restricted

cash balances and their classification within the

Statement of Financial Position and the Statement of

Cash Flows;

—The nature of royalty payments, how they are

determined and the extent to which they are recognized

in revenue or expenses.

The Group responded to the FRC with responses to their

inquiries and noted certain clarifying enhancements would

be made to relevant disclosures, following which the review

was closed. These enhancements have been included within

the 2023 Annual Report & Form 20-F.

An FRC review provides no assurance that the Group’s

2022 Annual Report was correct in all material respects.

The FRC’s role was not to verify the information provided,

but to consider compliance with reporting requirements. Its

letters are written on the basis that the FRC accepts no

liability for reliance on them by the Group or any third

party, including but not limited to investors

and shareholders.

Summary

For the year under review, and beyond, the Audit & Risk

Committee will continue its monitoring of financial

reporting and of internal controls and risk management, as

these evolve in response to the Group’s continuing growth

and new opportunities as they arise.

David J. Turner, Jr.

Chair of the Audit & Risk Committee

March 19, 2024

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	147

The Remuneration Committee’s

Report

Sylvia Kerrigan<br><br>(58)<br><br>Independent Non-Executive<br><br>Director (Chair)<br><br>Strength:<br><br>Industry, Governance<br><br>Independence from:<br><br>Management & Other<br><br>interests	David E. Johnson<br><br>(63)<br><br>Non-Executive Director,<br><br>Independent upon<br><br>Appointment<br><br>Strength:<br><br>Finance<br><br>Independence from:<br><br>Management & Other<br><br>interests	Sandra M. Stash<br><br>(64)<br><br>Independent Non-Executive<br><br>Director Strength:<br><br>Industry<br><br>Independence from:<br><br>Management & Other<br><br>interests	David J. Turner, Jr.<br><br>(60)<br><br>Independent Non-<br><br>Executive Director (as<br><br>of 1/1/23)<br><br>Strength:<br><br>Finance<br><br>Independence from:<br><br>Management & Other<br><br>interests

Letter from Chair of the

Remuneration Committee

I am pleased to present our 2023 Directors’ Remuneration

Report on behalf of the Board. Included within this report

is the Annual Report on Remuneration, which sets out

payments and awards made to the Directors for the year

ended 2023 and how the Directors’ Remuneration Policy

will operate for the year ended December 31, 2024 and a

summary of the Directors’ Remuneration Policy for which

shareholder approval was obtained at the 2022 Annual

General Meeting and which will continue to apply without

amendment for the forthcoming year. The Director’s

Remuneration Report will be presented to shareholders for

approval at the 2024 Annual General Meeting.

Key Objective

The Remuneration Committee oversees the remuneration

program of Executive Directors and the Senior Leadership

Team (“executives”) on behalf of the Board. The

Remuneration Committee is focused on ensuring that

remuneration is designed to emphasize "pay for

performance” by:

—Providing performance-driven remuneration

opportunities that attract, retain and motivate executives

to achieve optimal results for the Group and

its shareholders;

—Aligning remuneration with the Group’s short- and

long-term business objectives while providing sufficient

flexibility to address the unique dynamics of the Group’s

business model; and

—Emphasizing the use of equity-based remuneration to

motivate the long-term retention of the Group’s

executives and align their interests with those

of shareholders.

As an executive's seniority increases, and the scope, duties

and responsibilities of the executive's position expand, the

Remuneration Committee believes a greater portion of total

remuneration should be performance driven and be based

on a longer time horizon. Fixed remuneration should

therefore be a relatively smaller portion of senior executive

total remuneration with the majority of an executive’s

realized remuneration being driven by the performance of

the Group.

DEC’S PERFORMANCE IN 2023

2023 was a year of continued execution and transition. The

Group brought a focused execution on increased cash flow

generation, capital discipline, and balance sheet

management. The year also marked a transition as the

Group closed the accretive Tanos II acquisition, which

expanded Central Region upstream and midstream assets,

established a dual listing on the New York Stock Exchange,

and completed its seventh Asset-Backed Securitization that

further enhanced the Group’s liquidity.

Through its continual, daily focus on SAM and its zero

tolerance policy for fugitive emissions, the Group made

significant progress in its emissions reduction goals,

including through its handheld and aerial leak detection

and repair programs and methane-driven pneumatic device

conversions to compressed air. Further, the Group

expanded asset retirement operations, deploying 17 rigs

across Appalachia to retire a combined 383 wells –

including 182 state and federal owned orphan wells and

other third-party owned wells and 201

Diversified-owned wells.

The Group’s formal Community Giving and Engagement

Program also made meaningful contributions to

surrounding communities, with more than $2 million

contributed to various charitable, education related, and

community and stakeholder engagement and outreach

groups, and community organizations, including to food

pantries, arts and educational programs, health and

wellness organizations, and municipal services.

148	Diversified Energy Company PLC Annual Report and Form 20-F2023

These achievements combined with the year’s equity

performance has impacted the performance-related pay

outcomes for the Executive team. With respect to the 2023

annual bonus, as reported elsewhere in this Annual Report

& Form 20-F, DEC’s adjusted EBITDA for 2023 was $543

million. This equated to adjusted EBITDA per basic share of

$11.51, or $11.57 per diluted share, after making certain

adjustments for acquisitions and share dilution as described

on page 160. The threshold, target and stretch metric was

$10.60, $11.64 and $12.60 per share, respectively, Metrics

were established using the 2023 budget, with the stretch

metric achievable from over-performing in production,

management of costs, and/or executing on acquisitions.

Due to adjusted EBITDA per share being between the

threshold and target levels the committee awarded 36% for

this metric out of a potential 50%.

Under the cash cost metric the Group achieved $1.26 per

Mcfe, which is similar to the Group’s KPI for adjusted

operating cost per Mcfe, yet excludes certain adjustments

for acquisitions and production taxes. The threshold, target

and stretch metric was $1.27, $1.21 and $1.18 per Mcfe,

respectively. As such, the committee awarded 7% for this

metric out of a potential 20%.

In relation to the non-financial elements which account for

the remainder of the annual award, the two Executive

Directors (CEO and COO) were determined to have

performed towards the top end of the objectives (20% of

potential 30%). The Group’s overall performance resulted in

awards of 110.1% of salary out of a maximum of 175% of

salary being awarded to the CEO and awards of 94.4% of

salary out of a maximum of 150% of salary being awarded

to the COO under the annual bonus plan.

The 2023 financial year was the end of the three-year

performance period for the Performance Share Award

granted in 2021. The performance conditions are a mix of

Return on Equity (“ROE”) (40%), Absolute TSR (40%) and

Relative TSR (20%) targets measured over three years. The

overall payout for the award is 40% of maximum.

The 2023 financial year was also the end of the

performance period for one tranche of stock options

(“Options”) for the Executive Directors. The 3rd tranche of

the Options granted in 2019 vested at 0%. These Options

vested in three tranches based on performance ending

2021, 2022, 2023 and were subject to an Adjusted EPS

condition and Absolute TSR condition.

The committee considers that the Remuneration Policy

operated as intended during 2023 and that the

remuneration outcomes described above reflect the overall

performance by the Group. The committee determined that

no discretion needed to be applied for the above

remuneration outcomes.

Key Matters Discussed by

the Committee

The key activities carried out by the committee in 2023

with the support of key management team individuals

including the President and Chief Financial Officer,

Chief Legal & Risk Officer, and Chief Human Resources

Officer, included:

—Determining 2023 annual bonus outcomes for an

Executive Director;

—Determining base salaries of the Executive Director for

the period starting January 2024;

—Reviewing the annual total remuneration of the

Group’s executives;

—Reviewing the Group’s overall workforce remuneration

and benefits plans, ensuring alignment of incentives and

rewards with culture;

—Reviewing and approving the 2024 Executive Director

Bonus Plan and Performance Share Award targets;

—Discussed the voting results of the 2023 AGM;

—Determination that the remuneration policy for 2023

operated as intended;

—Preparing the Directors’ Remuneration Report; and

—Reviewing and updating the committee’s Terms of

Reference to reflect best practices.

DIRECTORS’ REMUNERATION POLICY

APPROVED AT THE 2022 AGM

The current policy was approved by shareholders in a

binding vote at the 2022 AGM with just under 83% of votes

cast in favor. The main features of the current package are

as follow:

—Base salaries which are broadly in-line with UK norms;

—A standard package of benefits but no pension provision;

—Annual bonus opportunity of 175% of base salary for the

CEO and 150% of salary for an Executive Director COO of

which any bonus in excess of 100% of salary is deferred

for one year;

—From 2023, Performance Share Awards with a maximum

of 325% of salary for the CEO and 275% of salary for an

Executive Director COO; and

—A shareholding requirement set at 300% of salary for the

CEO and 250% of salary for the COO whilst in

employment and a two-year post cessation

shareholding guideline.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	149

Implementation of Directors’

Remuneration Policy for 2024

The committee has ensured that the executive

remuneration policy and practices, as well as the

committee’s charter, are consistent with the six factors set

out in Provision 40 of the Corporate Governance Code.

Matters to be Approved at our

Annual General Meeting

As no changes are proposed to the existing Policy, only one

remuneration resolution will be tabled at the 2024 AGM,

namely the advisory shareholder vote on the Directors'

Remuneration Report.

Our approach to executive pay is designed to address the

challenge of balancing a U.S. based management team with

the expectations of a UK and U.S. listed company. I hope

that our shareholders will remain supportive of the

approach and that you will vote in favor of the

remuneration resolution at the 2024 AGM.

Sylvia Kerrigan

Chair of the Remuneration Committee

March 19, 2024

Membership

The committee is currently comprised of the Non-Executive

Chairman and three Independent Non-Executive Directors:

Sylvia Kerrigan, the Remuneration Committee Chair, Sandra

M. Stash, David J. Turner, Jr., and David E. Johnson.

Benjamin Sullivan, Senior Executive Vice President, Chief

Legal & Risk Officer and Corporate Secretary acts as

Secretary to the committee.

Meetings and Attendance

The Remuneration Committee met formally seven times

during the year and has met twice thus far in 2024. The

committee regularly meets in private executive session at

the end of its committee meetings, without management

present to ensure that points of common concern are

identified and that priorities for future attention by the

committee are agreed upon. The Chair of the committee

keeps in close contact with the Chief Legal & Risk Officer

and Human Resources team between committee meetings.

For committee meeting attendance for each Director

see the Directors’ Report within this Annual Report & Form

20-F.

COMMITTEE EFFECTIVENESS

—The committee performed a critical analysis internal

review and evaluation on itself, as part of its annual self-

review process. No significant areas of concern

were raised.

Responsibilities and Terms

of Reference

A key objective of the committee is to help attract, retain

and motivate talented executives by ensuring competitive

remuneration and motivating incentives. The incentives are

linked to the overall performance of the Group and, in turn,

to the interests of all shareholders.

The Remuneration Committee is responsible for:

—Discussing and determining the Group’s framework for

executive remuneration;

—Determining the remuneration for the Executive Director;

—Reviewing remuneration for other members of the Senior

Leadership Team;

—Reviewing and recommending to the Board the

remuneration of the Non-Executive Directors; and

—Overseeing and reviewing the structure and operation of

the remuneration policy.

The committee has formal terms of reference which can be

viewed on the Group’s website at www.div.energy.

150	Diversified Energy Company PLC Annual Report and Form 20-F2023

Role of Management

The Group’s Human Resources Department assists

the Remuneration Committee and its independent

compensation consultant (as applicable) in gathering the

information needed for their respective reviews of the

Group’s compensation program with respect to the Senior

Leadership Team. This assistance includes assembling

requested compensation data. The CEO develops pay

recommendations for members of the Senior Leadership

Team for review and discussion by the committee. The

committee, in private session and without executive officers

present, approves the CEO’s pay levels.

Committee Considerations

Consistent with the six factors set out in Provision 40 of

the UK Corporate Governance Code, when determining

the Directors’ Remuneration Policy and practices, the

committee has determined there are no significant

changes from the prior year and has continued to address

the following:

Clarity – the Directors’ Remuneration Policy is well

understood by our executives and has been clearly

articulated to Shareholders;

Simplicity – the committee believes the remuneration

structure is simple and well understood. The design has

avoided any complex structures which have the potential to

deliver unintended outcomes;

Risk – the Directors’ Remuneration Policy and approach to

target setting seek to discourage inappropriate risk-taking.

Malus and clawback provisions apply;

Predictability – executives’ incentive arrangements are

subject to individual participation caps. An indication of the

range of values in packages is provided in the remuneration

scenario charts. The final value of any share awards is based

on achieving performance criteria and for shares issued

their final values will depend on share price at the time

of vesting;

Proportionality – there is a clear link between individual

awards, delivery of strategy and our long-term

performance; and

Alignment to Culture – pay and policies cascade down the

organization and are fully aligned to the Group’s culture

and specifically to “pay for performance”.

External Advisors

During the year, FIT Remuneration Consultants LLP (“FIT”),

signatories to the Remuneration Consultants Group’s Code

of Conduct, provided advice to the committee on all

matters relating to remuneration, including best practice.

FIT provided no other services to the Group or its Directors

and does not have any other connection with the Group or

its Directors. Accordingly, the committee was satisfied that

the advice provided by FIT was objective and independent.

The committee selected and appointed FIT based on the

positive experience with FIT in prior years, among other

factors. FIT’s fees in respect of 2023 were $35,702 (GBP:

£28,006), plus value added tax. FIT’s fees were charged on

the basis of the firm’s standard terms of business for

advice provided.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	151

152	Diversified Energy Company PLC Annual Report and Form 20-F2023

Our approach to

executive pay is

designed to address

the challenge of

balancing a U.S.

based management

team with the

expectations of a

UK and U.S. listed

company.

Remuneration at a Glance

REMUNERATION POLICY AND IMPLEMENTATION

Stated Objective	Overview of Policy	Implementation for 2024
Base salary	—Reviewed annually.<br><br>—Consideration given to the performance of the<br><br>Group, the individual’s performance, the<br><br>individual responsibilities or scope of the role,<br><br>and pay practices in relevant comparator<br><br>companies in both the UK and U.S.	Executive Director(a):—CEO: Rusty Hutson, Jr.: 779,834
Pension and<br><br>benefits	—The current Executive Director does not receive<br><br>a pension contribution and any future provision<br><br>will be aligned to the wider workforce.	—The current Executive Director does not receive a pension contribution.—In line with the approach taken for all employees, the Group offers a retirement plan in accordance with subsection 401(k) of the Internal Revenue Code in which the Executive Director may make voluntary pre-tax contributions towards his own retirement. The Group matches the Executive Director’s contributions up to 26 thousand per annum.—Benefits consist of standard car and health/insurance related benefits.
Annual bonus	—Maximum of 175% of salary for Rusty Hutson, Jr.<br><br>—Paid in cash up to 100% of base salary;<br><br>Outcomes above this level deferred as either<br><br>shares or cash (at the individual’s discretion)<br><br>for one year provided continued service.<br><br>—Subject to the achievement of relevant<br><br>performance conditions, both qualitative<br><br>and quantitative.<br><br>—Subject to malus and clawback provisions.	Potential awards for 2024 performance period:—Rusty Hutson, Jr.: 175% of salary—Performance conditions, which will have defined Threshold, Target, and Stretch payout criteria:

			30% ESG/EHS
Long-term<br><br>incentives	—Performance Share Awards, subject to service<br><br>and performance over a three-year period, and<br><br>eligible for payment of applicable Dividend<br><br>Equivalent Rights during the vesting period.<br><br>—Maximum award of 325% of salary for<br><br>Rusty Hutson, Jr.<br><br>—Subject to malus and clawback provisions.	Potential awards for 2024:—Rusty Hutson, Jr.: 325% of salary—Performance conditions:
			10% relative<br><br>TSR
			20% emissions
Share ownership<br><br>requirements	—Rusty Hutson, Jr.: 300% of salary<br><br>—Continues to apply for first year post-<br><br>employment, reducing to 200% of salary for the<br><br>second year.	—Rusty Hutson, Jr. meets the requirement.

All values are in US Dollars.

(a)Effective January 1, 2024 and represents a 4% increase for Rusty Hutson, Jr. over 2023. This compares to increases across the Group ranging

from 0% to 10% based on performance, with an average of 4%.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	153

INTRODUCTION

Part A: Summarizes the Director’s Remuneration Policy which was approved by shareholders at the AGM held on April 26,

2022 (the “Directors’ Remuneration Policy”).

Part B: Constitutes the Annual Report on Remuneration sections of the Executive Directors’ Remuneration Report.

PART A: DIRECTORS’ REMUNERATION POLICY

A summary of the main sections of the Directors’ Remuneration Policy, which was approved by shareholders at the 2022 AGM,

is shown below. Certain details have been updated to reflect the implementation of the policy for the year ended December 31,

The policy as approved by the Group’s shareholders can be found within our 2021 Annual Report and Accounts which

are available on our website at https://ir.div.energy/reports-announcements.

The following table summarizes the Group’s policies in respect of the key elements of our Directors’ remuneration:

Element and<br><br>Purpose	Policy and Operation	Maximum	Performance Measures
Base salary<br><br>This is the core<br><br>element of pay<br><br>and reflects the<br><br>individual’s role<br><br>and position<br><br>within the Group<br><br>with some<br><br>adjustment to<br><br>reflect their<br><br>capability and<br><br>contribution.	—Base salaries will typically be<br><br>reviewed annually, with<br><br>consideration given to the<br><br>performance of the Group and the<br><br>individual, any changes in<br><br>responsibilities or scope of the<br><br>role and pay practices in relevant<br><br>U.S. and UK comparator<br><br>companies of a broadly similar<br><br>size and complexity, with due<br><br>account taken of both market<br><br>capitalization and turnover.<br><br>—The committee does not strictly<br><br>follow benchmark pay data, but<br><br>instead uses it as one of a number<br><br>of reference points when<br><br>considering, in its judgment, the<br><br>appropriate level of salary. Base<br><br>salary is paid monthly in cash.	—It is anticipated that salary<br><br>increases will generally be<br><br>in line with those awarded<br><br>to the general workforce.<br><br>That said, in certain<br><br>circumstances (including,<br><br>but not limited to, changes<br><br>in role and responsibilities,<br><br>market levels, individual and<br><br>Group performance), the<br><br>committee may make larger<br><br>salary increases to ensure<br><br>they are market<br><br>competitive. The rationale<br><br>for any such increase will be<br><br>disclosed in the relevant<br><br>Annual Report.	n/a
Benefits<br><br>To provide<br><br>benefits valued<br><br>by recipients.	—The Executive Director currently<br><br>receives standard car and health/<br><br>insurance related benefits.<br><br>—Where appropriate, the Group will<br><br>meet certain costs relating to<br><br>Executive Director relocations.<br><br>—In line with the approach taken for<br><br>all employees, the Group offers a<br><br>retirement plan in accordance<br><br>with subsection 401(k) of the<br><br>Internal Revenue Code in which<br><br>the Executive Director may make<br><br>voluntary pre-tax contributions<br><br>towards his own retirement. The<br><br>Group matches the Executive<br><br>Director’s contributions up to $26<br><br>thousand per annum.<br><br>—The committee reserves the<br><br>discretion to introduce new<br><br>benefits where it concludes that<br><br>it is appropriate to do so, having<br><br>regard to the particular<br><br>circumstances and to<br><br>market practice.	—It is not possible to<br><br>prescribe the likely change<br><br>in the cost of insured<br><br>benefits or the cost of some<br><br>of the other reported<br><br>benefits year to year.<br><br>—Relocation expenses are<br><br>subject to a maximum limit<br><br>of 100% of base salary,<br><br>provided that such<br><br>expenses may be paid only<br><br>in the year of appointment<br><br>and for a further two<br><br>financial years.<br><br>—With limited exceptions, the<br><br>U.S. Section 401(k) defined<br><br>contribution plan currently<br><br>provides company<br><br>matching contributions up<br><br>to a maximum of $26<br><br>thousand per annum.<br><br>—The committee will monitor<br><br>the costs of benefits in<br><br>practice and will ensure that<br><br>the overall costs do not<br><br>increase by more than what<br><br>the committee considers<br><br>appropriate in all the<br><br>circumstances.	n/a
154	Diversified Energy Company PLC Annual Report and Form 20-F2023
---	---
Element and<br><br>Purpose	Policy and Operation	Maximum	Performance Measures
---	---	---	---	---
Pension<br><br>To provide<br><br>retirement<br><br>benefits.	—Currently, no element of the<br><br>Directors’ remuneration is<br><br>pensionable, and the Group does<br><br>not operate any pension scheme<br><br>or other scheme providing<br><br>retirement or similar benefits.<br><br>—The committee reserves the<br><br>discretion to introduce new<br><br>benefits where it concludes that it<br><br>is appropriate to do so, having<br><br>regard to the particular<br><br>circumstances and to<br><br>market practice.	—The current Executive<br><br>Director does not receive a<br><br>pension contribution.<br><br>—Any future pension<br><br>provision will be limited to<br><br>levels aligned to the<br><br>contribution levels for the<br><br>majority of the workforce.	n/a
Annual bonus<br><br>plan<br><br>To motivate the<br><br>Executive<br><br>Director and<br><br>incentivize the<br><br>delivery of<br><br>performance<br><br>over a one-year<br><br>operating cycle,<br><br>focusing on the<br><br>short- to<br><br>medium-term<br><br>elements of our<br><br>strategic aims.	—Annual bonus plan levels and the<br><br>appropriateness of measures are<br><br>reviewed annually at the<br><br>commencement of each financial<br><br>year to ensure they continue to<br><br>support our strategy.<br><br>—Once set, performance measures<br><br>and targets will generally remain<br><br>unchanged for the year, except to<br><br>reflect events such as corporate<br><br>acquisitions or other major<br><br>transactions where the committee<br><br>considers it to be necessary in its<br><br>opinion to make appropriate<br><br>adjustments.<br><br>—Annual bonus plan outcomes can<br><br>be paid in cash up to 100% of<br><br>base salary. Outcomes above this<br><br>level will be deferred as either<br><br>cash or shares (at the individual’s<br><br>discretion) for one year provided<br><br>continued service. During the<br><br>deferral period, the value of any<br><br>dividends (if deferred as shares)<br><br>will be paid in cash or shares.<br><br>—Clawback provisions apply to the<br><br>annual bonus plan, and malus and<br><br>clawback will apply to deferred<br><br>shares in accordance with the<br><br>Group’s clawback and<br><br>malus policies.	—The maximum level of<br><br>annual bonus plan<br><br>outcomes is 175% of base<br><br>salary for the CEO.	—The performance measures<br><br>applied may be financial or<br><br>non-financial; quantitative and<br><br>qualitative; and corporate,<br><br>divisional or individual and<br><br>with such weightings as the<br><br>committee considers<br><br>appropriate. The metrics and<br><br>weightings applicable in 2024<br><br>are as follows:
				50% adjusted EBITDA<br><br>per share
				20% cash cost per Mcfe
				30% ESG/EHS
			—Where a sliding scale of<br><br>targets is used, attaining the<br><br>threshold level of performance<br><br>for any measure will not<br><br>typically produce a payout of<br><br>more than 25% of the<br><br>maximum portion of the<br><br>overall annual bonus<br><br>attributable to that measure,<br><br>with a sliding scale to full<br><br>payout for maximum<br><br>performance.<br><br>—However, the annual bonus<br><br>plan remains a discretionary<br><br>arrangement and the<br><br>committee retains a standard<br><br>power to apply its discretion<br><br>to adjust the outcome of the<br><br>annual bonus plan for any<br><br>performance measure (from<br><br>zero to any cap), should it<br><br>consider that to<br><br>be appropriate.		Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	155
---	---	---	---	---
Element and<br><br>Purpose	Policy and Operation	Maximum	Performance Measures
---	---	---	---	---
Long-term<br><br>incentives<br><br>To motivate and<br><br>incentivize the<br><br>delivery of<br><br>sustained<br><br>performance<br><br>over the long-<br><br>term, and to<br><br>promote<br><br>alignment with<br><br>shareholders’<br><br>interests, the<br><br>Group grants<br><br>Performance<br><br>Share Awards.	—Performance Share Awards vest<br><br>over a period of three years, with<br><br>awards vesting to the extent<br><br>that performance conditions<br><br>are satisfied.<br><br>—Vested awards for the Executive<br><br>Director will be subject to a<br><br>further two-year holding period<br><br>during which time awards may<br><br>not normally be exercised or<br><br>released but are no longer<br><br>contingent on performance<br><br>conditions or future employment.<br><br>—After the vesting period, the value<br><br>of any dividends accrued during<br><br>the vesting period on<br><br>Performance Share Awards will be<br><br>paid in shares and will be subject<br><br>to a further two-year holding<br><br>period, or paid in cash at the<br><br>end of a further two-year<br><br>holding period.<br><br>—Clawback and malus provisions<br><br>apply to Performance<br><br>Share Awards.	—Performance Share Awards<br><br>may be granted with a<br><br>maximum value of 325% of<br><br>base salary per financial<br><br>year to the CEO.<br><br>—In determining the number<br><br>of shares subject to an<br><br>award, the market value of<br><br>a share shall, unless the<br><br>committee determines<br><br>otherwise, be assumed to<br><br>be the average share price<br><br>for the five days following<br><br>the announcement of the<br><br>Group’s results for the<br><br>previous financial year.	—The committee may set such<br><br>performance conditions on<br><br>Performance Share Awards as<br><br>it considers appropriate,<br><br>whether financial or non-<br><br>financial and whether<br><br>corporate, divisional or<br><br>individual. Performance<br><br>periods may be over such<br><br>periods as the committee<br><br>selects at grant, which will not<br><br>be less than, but may be<br><br>longer than, three years.<br><br>—The metrics and weightings<br><br>applicable in 2024 are<br><br>as follows:
				40% Return on Equity
				30% Absolute TSR
				10% Relative TSR
				20% Emissions
			—No more than 15% of awards<br><br>vest for attaining the threshold<br><br>level of performance<br><br>conditions. The committee<br><br>also has a standard power to<br><br>apply its judgment to adjust<br><br>the formulaic outcome of all<br><br>performance measures to take<br><br>account of any circumstances<br><br>(including the performance of<br><br>the Group, any individual or<br><br>business) should it consider<br><br>that to be appropriate.		156	Diversified Energy Company PLC Annual Report and Form 20-F2023
---	---
Element and<br><br>Purpose	Policy and Operation	Maximum	Performance<br><br>Measures
---	---	---	---
Share ownership<br><br>guidelines<br><br>To further align<br><br>the interests of<br><br>the Executive<br><br>Director with<br><br>those of<br><br>shareholders.	—The Executive Director is expected to build up a<br><br>prescribed level of shareholding.<br><br>—Minimum shareholding is 300% of base salary<br><br>for the CEO. The committee reserves the power<br><br>to amend, but not reduce, these levels in<br><br>future years.<br><br>—To the extent that the prescribed level has not<br><br>been reached, the Executive Director will be<br><br>expected to retain a proportion of the shares<br><br>vesting under the Group’s share plans until the<br><br>guideline is met.<br><br>—Any vested Performance Share Award shares<br><br>subject to a holding period and any shares<br><br>awarded in connection with annual bonus<br><br>deferral will be included for the purpose of the<br><br>guidelines (discounted for anticipated<br><br>tax liabilities).<br><br>—A post-employment shareholding requirement<br><br>normally applies to Performance Share Award<br><br>shares vesting after the effective date of the<br><br>Directors’ Remuneration Policy for 2022. The<br><br>policy requires the Executive Director to hold<br><br>the shares equivalent to his share ownership<br><br>guideline at that date, for a period of one year<br><br>post-employment and reducing to 200% of<br><br>salary for the second year post-employment.	n/a	n/a
Chairman’s and<br><br>Non-Executive<br><br>Directors’ fees<br><br>To enable the<br><br>Group to recruit<br><br>and retain a<br><br>Chairman of the<br><br>Board and Non-<br><br>Executive<br><br>Directors of the<br><br>highest caliber.	—The fees paid to the Chairman and Non-<br><br>Executive Directors aim to be competitive with<br><br>other U.S. and UK listed peers of equivalent size<br><br>and complexity.<br><br>—The fees payable are determined by the Board,<br><br>and will include incremental committee Chair<br><br>and additional responsibility fees (as<br><br>applicable). Directors do not participate in<br><br>decisions regarding their own fees.<br><br>—Non-Executive Directors are reimbursed all<br><br>necessary and reasonable expenses incurred in<br><br>connection with the performance of their duties<br><br>and any tax thereon in accordance with the<br><br>Group’s Non-Executive Director Expense<br><br>Reimbursement Policy.<br><br>—No other benefits are envisaged for the<br><br>Chairman and Non-Executive Directors, but the<br><br>Group reserves the right to provide benefits,<br><br>including company related travel and<br><br>office support.	—Fees are paid monthly in cash.<br><br>—A proportion of each Non-<br><br>Executive Directors’ fees may be<br><br>required to be used for the<br><br>acquisition of Group shares which<br><br>must then be held until they<br><br>cease to be a Director.<br><br>—The aggregate fees and any<br><br>benefits of the Chairman and<br><br>Non-Executive Directors will not<br><br>exceed the limit from time to<br><br>time prescribed within the<br><br>Group’s Articles of Association<br><br>for such fees.<br><br>—Any increases actually made will<br><br>be appropriately disclosed.	n/a

SERVICE CONTRACTS AND LETTERS OF APPOINTMENT

The following table summaries key dates for the service contracts of Rusty Hutson, Jr. and Bradley G. Gray effective as of

December 31, 2023. Note that concurrent with Mr. Gray’s appointment as the Group’s President and Chief Financial Officer, he

resigned from the Board and is no longer an Executive Director effective as of September 15, 2023.

Name	Date of Service Contract	Duration
Rusty Hutson, Jr.	January 30, 2017	Each Executive Director’s service agreement should be of<br><br>indefinite duration, subject to termination by the Group or<br><br>the individual on six months’ notice. The service agreements<br><br>of all current Executive Directors comply with that policy.
Bradley G. Gray(a)	January 30, 2017
Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	157
---	---	---	---	---

The contract of the current Executive Director, which is available for inspection at the Group’s registered office, contains a

payment in lieu of notice clause which is limited to base salary only. In line with U.S. practice, depending on the circumstances

of their severance from service, the Executive Director may be entitled to certain payments, including previously accrued

salary plus 12 months salary. For each Non-Executive Director, the effective date of their latest letter of appointment is:

Name	Date of Letter of Appointment	Duration
David E. Johnson	February 3, 2017
Martin K. Thomas	January 1, 2015	Initial period of 12 months, subject to re-election at each<br><br>AGM of the Group and are terminable on three months’<br><br>notice given by either party.
David J. Turner, Jr.	May 27, 2019
Sandra M. Stash	October 21, 2019
Kathryn Klaber	January 1, 2023
Sylvia Kerrigan	October 11, 2021

The full policy included in the Group’s 2021 Annual Report also includes further information on the following:

—Malus and Clawback

—Travel and Hospitality

—Differences Between the Policy on Remuneration for Directors from the Policy on Remuneration of Other Staff

—Committee Discretions

—Recruitment Remuneration Policy

—Remuneration Policy on Termination

—External Appointments

—Committee Discretion

ILLUSTRATIONS OF APPLICATION OF EXECUTIVE DIRECTOR REMUNERATION POLICY

The following charts show how the remuneration policy for the Executive Director will be applied in 2024 using the

assumptions shown overleaf:

Minimum	—Consists of base salary, benefits and pension.<br><br>—Base salary is the salary to be paid in 2024.<br><br>—Benefits are the value received in 2023.<br><br>—No pension is provided, only 401(k) match to the extent applicable.
Target	Based on what the Executive Director would receive if performance was on-target (excluding share<br><br>price appreciation and dividends):<br><br>—Annual bonus: Consists of the target bonus (50% of maximum opportunity used for<br><br>illustrative purposes).<br><br>—Long-Term Incentives (“LTI”): Consists of the target level of vesting (50% vesting) of Performance<br><br>Share Awards (at 325% of salary for Rusty Hutson, Jr.).
Maximum	Based on the maximum remuneration receivable (excluding share price appreciation and dividends):<br><br>—Annual bonus: Consists of maximum bonus of 175% of base salary for Rusty Hutson, Jr.<br><br>—LTI: Consists of full vesting of Performance Share Awards (at 325% of salary for Rusty Hutson, Jr.).
Maximum with<br><br>share price growth	Based on the Maximum scenario set out above but with a 50% share price increase applied to the value<br><br>of Long-Term Incentive Plan (“LTIP”) awards.		($ thousands)	Base Salary	Benefits	Benefit Plan(a)	Total Fixed
---	---	---	---	---
Rusty Hutson, Jr.	$780	$12	$31	$823

(a)Reflects amounts received under the Group’s 401(k) contribution plan and health insurance benefits.

158	Diversified Energy Company PLC Annual Report and Form 20-F2023

ROBERT R. (RUSTY) HUTSON JR.

03_426107-1_stack_rusty huston.jpg

PART B: ANNUAL REPORT ON

REMUNERATION

The remuneration for the Executive and Non-Executive

Directors of the Group who performed qualifying services

during the year is detailed below. For the year ended

December 31, 2023, the aggregate compensation paid to

the members of our board of directors and our executive

officers for services in all capacities was approximately $4

million.

Executive officers are entitled to matching contributions

from the Group of up to $26 thousand per annum into their

401(k) retirement plans. They also receive a range of core

benefits such as life insurance, private medical coverage

and annual health screens.

The Non-Executive Directors received no remuneration

other than their annual fee. The aggregate fees and any

benefits of the Chairman of the Board and non-executive

directors will not exceed the limit from time to time

prescribed within the Group’s Articles of Association for

such fees which is currently £1,055,000 per annum. In

addition, non-executive directors are reimbursed all

necessary and reasonable expenses incurred in connection

with the performance of their duties and any tax thereon in

accordance with the Group’s Non-Executive Director

Expense Reimbursement Policy.

Directors’ remuneration for the years ended December 31, 2023 and 2022:

Executive Directors	Rusty Hutson, Jr.		Bradley G. Gray(a)
(In thousands)	December 31, 2023	December 31, 2022	December 31, 2023	December 31, 2022
Salary/Fees	$750	$720	$323	$437
Taxable Benefits(b)	12	12	8	12
Benefit Plan(c)	31	37	15	36
Pension(d)	—	—	—	—
Total Fixed Pay	793	769	346	485
Bonus(e)	825	1,072	305	558
Long-Term Incentives(f)	442	4,030	272	2,378
Total Variable Pay	1,267	5,102	577	2,936
Total Remuneration	$2,060	$5,871	$923	$3,421
Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	159
---	---	---	---	---
Non-Executive Directors - Total Remuneration (In thousands)	December 31, 2023	December 31, 2022
---	---	---
David E. Johnson	$216	$200
Martin K. Thomas	155	145
David J. Turner, Jr.	168	156
Sandra M. Stash	156	145
Kathryn Z. Klaber(g)	139	—
Sylvia Kerrigan	160	120

(a)Mr. Gray ceased to be a Director on September 15, 2023. The fixed pay figures represent the period Mr. Gray was a Director for the year

ended December 31, 2023.

(b)Taxable benefits were comprised of Group paid life insurance premiums and automobile reimbursements.

(c)Reflects matching contributions under the Group’s 401(k) plan and health insurance benefits.

(d)The Executive Directors do not receive a pension provision.

(e)Further details of the bonus outcome for 2023 can be found in the 2023 Annual Bonus for Executive Directors section within this Annual

Report & Form 20-F. For 2023, the bonus totals for Rusty Hutson, Jr., and Bradley G. Gray represent 110.1% and 94.4% of approved base

salary, respectively. The amounts above 100% of salary will be deferred compulsorily into either cash or shares for one year provided

continued service, without additional performance conditions. For 2022, the bonus totals for Rusty Hutson, Jr., and Bradley G. Gray

represent 148.75% and 127.5% of base salary, respectively. The amounts above 100% of salary were deferred into cash for one year provided

continued service, without additional performance conditions.

(f)For 2023, the value of the Performance Share Award granted in 2021, including dividend equivalent units (“DEUs”) accrued to date, has been

based on the number of shares and DEUs that will vest and the three-month average share price for the period to December 31, 2023

(£13.615 per share) using an exchange rate of £1:$1.24055. The overall payout for the Performance Share Award was 40% and the grant share

price for the awards was £23.96 and, accordingly, the relevant figures are reflective of a decrease of more than 43% in the Group’s share

price over the three year period.

(g)Appointed to the Board on January 1, 2023.

2023 ANNUAL BONUS FOR EXECUTIVE DIRECTORS

For 2023 the overall bonus plan for Executive Directors was a maximum of 175% of base salary for Mr. Hutson and 150% of

salary for Mr. Gray with an actual achieved formulaic bonus of 110.1% and 94.4%, respectively. The Group delivered a strong

operational performance in 2023. The following table summarizes the performance targets and outcomes which led to the

committee’s decisions as to the payout percentages.

The targets were as follows:

Measure	Threshold	Target(a)	Maximum<br><br>(100%<br><br>Payout)	Actual	% of Total<br><br>Bonus	Payout %
Adjusted EBITDA per share(b)	$10.60	$11.64	$12.60	$11.57	50%	35.9%
Cash cost per Mcfe(c)	$1.27	$1.21	$1.18	$1.26	20%	7.0%
ESG and EHS	(See below)				30%	20.0%
Total % of maximum						62.9%
Total % of salary - Rusty Hutson, Jr.						110.1%
Total % of salary - Bradley G. Gray						94.4%

(a)Target was 75% for the adjusted EBITDA per share and cash cost per Mcfe measures and 50% for the ESG and EHS measures, but for all

measures stretch allowed inclusion of acquisitions.

(b)Actual results for the adjusted EBITDA per share measure utilized fully diluted weighted average shares outstanding.

(c)Actual results for the cash cost per Mcfe measure excluded 2023 acquisitions and irregular G&A expense.

160	Diversified Energy Company PLC Annual Report and Form 20-F2023

In respect of the non-financial performance targets set for the Executive Directors, these were set against a range of strategic

targets at the start of the year. The targets set were aligned to the Group’s corporate objectives and strategy. Details of the

measures, to the extent they are not commercially sensitive are shown below.

		% of Total<br><br>Bonus	Payout<br><br>%
ESG - ENVIRONMENTAL
Target	Performance	15.00%	15.00%
Reduce methane intensity<br><br>Threshold: 6%<br><br>Target: 8%<br><br>Stretch: 10%	Achieved: 10%	10.00%	10.00%
Central emissions surveys<br><br>Threshold: N/A<br><br>Target: N/A<br><br>Stretch: 100%	Achieved: 100%	5.00%	5.00%
ESG - SOCIAL
Target	Performance	10.00%	5.00%
Reduce TRIR Rate:<br><br>Threshold: 1.12<br><br>Target: 1.03<br><br>Stretch: 0.97	Achieved: 1.28	5.00%	0.00%
Reduce MVA:<br><br>Threshold: 0.85<br><br>Target: 0.80<br><br>Stretch: 0.75	Achieved: 0.55	5.00%	5.00%
ESG - GOVERNANCE
Target	Performance	5.00%	0.00%
Diversity advisory team/Diversity training	Achieved: 0%	5.00%	0.00%

LONG-TERM INCENTIVES OUTCOME

2021 LTIP Awards

The performance period in respect of the Performance Share Award granted in 2021 came to an end on December 31, 2023.

Performance conditions were Return on Equity (40%), Absolute TSR (40%) and Relative TSR (20%) targets measured over

three years. The targets and outcomes are set out below:

	% of Total<br><br>Award	Threshold	Maximum	Achieved	Vesting % of<br><br>Component	Payout %(a)
Three-Year Average ROE(b)	40%	15%	25%	25%	100%	40%
Absolute TSR (per annum)	40%	10%	20%	(7%)	0%	0%
Three-Year TSR v FTSE 250	20%	Median	Upper Quartile	Below Median	0%	0%

(a)Calculated as % of total award multiplied by vesting % of component.

(b)Calculated as (adjusted EBITDA - recurring capital expenditures - interest expense) / invested equity.

Based on the vesting percentages above, the number of shares expected to vest in March 2024 and their estimated value

(based on the three-month average share price to December 31, 2023 of £13.615 per share ($16.89 per share based upon a

GBP:USD exchange rate of £1:$1.24055) are as follows:

	Maximum<br><br>number of<br><br>shares(a)	Number of<br><br>shares to<br><br>lapse(b)	Number of<br><br>Shares to<br><br>vest(c)	Estimated<br><br>value at<br><br>vesting(d)	Face value of<br><br>awards<br><br>vesting(e)	Impact of<br><br>share price on<br><br>vesting(f)
Rusty Hutson, Jr.	65,359	39,213	26,146	$441,606	$870,662	$(429,056)
Bradley G. Gray	40,183	24,108	16,075	271,507	535,298	(263,791)

(a)Includes 23,727 and 14,587 dividend equivalent units accrued over the performance period to date in the maximum number of shares that

will vest in March 2024 for Rusty Hutson Jr. and Bradley G. Gray, respectively.

(b)Includes 14,234 and 8,751 dividend equivalent units accrued over the performance period to date in the number of shares to lapse in March

2024 for Rusty Hutson Jr. and Bradley G. Gray, respectively.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	161

(c)Includes 9,493 and 5,836 dividend equivalent units accrued over the performance period to date in the number of shares to vest in March

2024 for Rusty Hutson Jr. and Bradley G. Gray, respectively.

(d)Based on the three-month average share price to December 31, 2023.

(e)Based on the number of shares vesting multiplied by the share price at the date of grant of £23.96 ($33.30 based upon a GBP:USD exchange

rate of £1:$1.3899).

(f)The grant share price for the award was £23.96 and accordingly the relevant figures are reflective of a decrease of 43% in the Group’s share

price comparing the award price to the estimated vesting price.

The award also received the value of dividend equivalent rights.

2019 Options

The performance period in respect of the third tranche of the Options granted in 2019 came to an end on December 31, 2023.

Performance conditions were Adjusted EPS and Annualized TSR on an equally weighted basis. The targets and outcomes are

set out below:

	Threshold	Maximum	Achieved	Vesting % of<br><br>Component
Adjusted EPS	£3.80	£4.40	£2.20	0%
Annualized TSR	10%	20%	3%	0%

The number of shares expected to vest in March 2024 is shown below:

	Exercise Price	Number of<br><br>Shares in<br><br>Tranche	Vesting %	Number of<br><br>Shares Vesting
Rusty Hutson, Jr.	£24.00	40,000	0%	0
Bradley G. Gray	£24.00	18,333	0%	0

SHARE AWARDS GRANTED IN 2023

2023 LTIP Awards

During the year, the Executive Directors received a Performance Share Award (conditional shares), which may vest after a

three-year performance period which will end on December 31, 2025, based on the achievement of stretching performance

conditions.

	Value of Award as<br><br>a % of Base Salary	Face Value of<br><br>Award ($)	Number of Shares
Rusty Hutson, Jr.	300%	$2,250,000	98,045
Bradley G. Gray	250%	1,137,500	49,567

In line with the ongoing policy, the share price used to

calculate the award was £18.694, being the average share

price over the five-day period commencing on March 21,

2023, the date that the Group issued its final 2022 results.

The awards are based upon a GBP:USD exchange rate of £1:

$1.2276, which was the exchange rate at the date of grant.

The date of grant was March 21, 2023. The LTIP Awards will

vest following completion of the performance period

(January 1, 2023 - December 31, 2025), and no later than

March 31, 2026, and vested shares will also be subject to a

further two-year holding period.

The performance conditions are a weighted mix of Return

on Equity (40%), Absolute TSR (30%), Relative TSR (10%)

and Emissions (20%) targets measured over three years as

described below. These measures encourage the generation

of sustainable long-term returns to shareholders. In

determining the level of vesting, the Remuneration

Committee will consider that the outcome of the

measurement reflects the underlying performance or

financial health of the Group.

RETURN ON EQUITY (40% OF TOTAL AWARD)		ABSOLUTE TSR (30% OF TOTAL AWARD)
Three-Year Average<br><br>ROE(a)	% of that Part of the Award<br><br>that Vests	Three-Year TSR	% of that Part of the Award<br><br>that Vests
Below 15% per annum	0%	Below 10% per annum	0%
15% per annum	15%	10% per annum	15%
25% per annum or above	100%	20% per annum or above	100%
15% to 25% per annum	Pro rata straight-line between<br><br>15% and 100%	10% to 20% per annum	Pro rata straight-line between<br><br>15% and 100%
162	Diversified Energy Company PLC Annual Report and Form 20-F2023
---	---
RELATIVE TSR (10% OF TOTAL AWARD)		EMISSIONS (20% OF TOTAL AWARD)
---	---	---	---
Three-Year TSR v FTSE<br><br>250	% of that Part of the Award<br><br>that Vests	Emissions over<br><br>Three Years	% of that Part of the Award<br><br>that Vests
Below median	0%	Below 8% Methane<br><br>Intensity Reduction	0%
Median	15%	8% Methane Intensity<br><br>Reduction	15%
Upper quartile or above	100%	20% Methane Intensity<br><br>Reduction	100%
Median to upper quartile	Pro rata straight-line between 15%<br><br>and 100%	8% to 20% Methane<br><br>Intensity Reduction	Pro rata straight-line between 15%<br><br>and 100%

(a)Calculated as adjusted EBITDA - recurring capital expenditures - interest expense) / invested equity.

OUTSTANDING EXECUTIVE DIRECTOR SHARE PLAN AWARDS

Details of all outstanding share awards as of December 31, 2023 made to Executive Directors are set out below:

Rusty Hutson, Jr.
Award<br><br>Type	Exercise<br><br>Price<br><br>(£)	Grant Date	Interest at<br><br>January 1,<br><br>2023	Awards<br><br>Granted<br><br>in the<br><br>Year	Accrued<br><br>Dividend<br><br>Equivalents	Awards<br><br>Exercised<br><br>in the<br><br>Year	Awards<br><br>Lapsed<br><br>in the<br><br>Year	Interest at<br><br>December<br><br>31, 2023(a)	Exercise/Vesting<br><br>Period
PSU		March 21, 2023	—	98,045	26,006	—	—	124,051	March 2026	(b)
PSU		March 15, 2022	81,275	—	17,994	—	—	99,269	March 2025	(c)
PSU		March 15, 2021	53,512	—	11,847	—	39,213	26,146	March 2024	(d)
Options	£24.00	May 9, 2019	46,600	—	—	—	40,000	6,600	May 2022<br><br>- May 2029	(f)
Options	£16.80	April 14, 2018	64,333	—	—	—	—	64,333	May 2021<br><br>- May 2028	(g)
Bradley G. Gray
Award<br><br>Type	Exercise<br><br>Price<br><br>(£)	Grant Date	Interest at<br><br>January 1,<br><br>2023	Awards<br><br>Granted<br><br>in the<br><br>Year	Accrued<br><br>Dividend<br><br>Equivalents	Awards<br><br>Exercised<br><br>in the<br><br>Year	Awards<br><br>Lapsed<br><br>in the<br><br>Year	Interest at<br><br>December<br><br>31, 2023(a)	Exercise/Vesting<br><br>Period
PSU		March 21, 2023	—	49,567	13,146	—	—	62,713	March 2026	(b)
PSU		March 15, 2022	41,640	—	9,218	—	—	50,858	March 2025	(c)
PSU		March 15, 2021	32,899	—	7,284	—	24,108	16,075	March 2024	(d)
Options	£24.00	May 9, 2019	21,358	—	—	—	18,333	3,025	May 2022<br><br>- May 2029	(e)
Options	£16.80	April 14, 2018	29,485	—	—	—	—	29,485	May 2021<br><br>- May 2028	(f)

(a)A performance factor of 40.0% was applied to 41,632 of the awards granted to Mr. Hutson and 25,596 of the awards granted to Mr. Gray in

March 2021, and 23,727 and 14,587 dividend equivalent units accrued over the performance period to date, respectively, resulting in

remaining interest of 26,146 and 16,075 total units vesting in March 2024, respectively. A performance factor of 0% was applied to 40,000 of

the awards granted to Mr. Hutson and 18,333 of the awards granted to Mr. Gray in May 2019, resulting in no options vesting in March 2024

and remaining interest of 6,600 and 3,025, respectively, which consists entirely of vested but unexercised options.

(b)Refer to Share Awards Granted in 2023 above for details of performance conditions.

(c)Refer to the Group's 2022 Annual Report and Accounts for details of performance conditions.

(d)Refer to the Group's 2021 Annual Report and Accounts for details of performance conditions.

(e)Options granted on May 9, 2019 with an exercise price of £24.00 per share with a three-year ratable vesting period. 100% of the Options are

subject to performance conditions.

(f)Options granted on April 14, 2018 with an exercise price of £16.80 per share with a three-year ratable vesting period. Two-thirds of the

Options are subject to performance conditions.

During the year ended December 31, 2023, the highest closing price of the Group’s shares was £23.72 and the lowest closing

price was £10.78. At December 31, 2023 the closing share price was £11.15.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	163

STATEMENT OF DIRECTORS’ SHAREHOLDING AND SHARE INTERESTS

The table below details, for each Director, the total number of Directors’ interests in shares at December 31, 2023:

	Shareholding	Shareholding<br><br>Required (% of<br><br>Salary)	Compliance With<br><br>Share Ownership<br><br>Guidelines	Share Interests
Rusty Hutson, Jr.	1,207,645	300%	ü	320,399	(a)
Bradley G. Gray	146,947	–	N/A	162,156	(b)
David E. Johnson	23,750	–	(c)	—
Martin K. Thomas	112,250	–	(c)	—
David J. Turner, Jr.	26,923	–	(c)	—
Sandra M. Stash	2,234	–	(c)	—
Kathryn Z. Klaber	1,050	–	(c)	—
Sylvia Kerrigan	1,341	–	(c)	—

(a)A performance factor of 40.0% was applied to 41,632 of the awards granted to Mr. Hutson in March 2021 and 23,727 dividend equivalent

units accrued over the performance period to date, resulting in remaining interest of 26,146 total units vesting in March 2024. A performance

factor of 0% was applied to 40,000 of the awards granted to Mr. Hutson in May 2019, resulting in no options vesting in 2023. As of

December 31, 2023, 70,933 vested options remained unexercised. All other awards were unvested as of December 31, 2023.

(b)A performance factor of 40.0% was applied to 25,596 of the awards granted to Mr. Gray in March 2021 and 14,587 dividend equivalent units

accrued over the performance period to date, resulting in remaining interest of 16,075 total units vesting in March 2024. A performance

factor of 0% was applied to 18,333 of the awards granted to Mr. Gray in May 2019, resulting in no options vesting in 2023. As of December 31,

2023, 32,510 vested options remained unexercised. All other awards were unvested as of December 31, 2023.

(c)The Non-Executive Directors purchase shares twice annually pursuant to the Non-Executive Director Share Purchase Program implemented

in 2022. Shares purchased under the Non-Executive Director Share Purchase Program must be held until retirement from the Board. While

this is not part of the Share Ownership Guidelines, each Non-Executive Director is in compliance with the parameters of the Non-Executive

Director Share Purchase Program.

PAYMENTS TO PAST DIRECTORS

Robert Post retired as a Board member in April 2020.

Mr. Post continued to provide advice to the Board post-

retirement as a consultant, receiving fees in 2023 of

$97,500.

PAYMENTS FOR LOSS OF OFFICE

Bradley G. Gray resigned from the Board effective as of

September 15, 2023 and received no payment for loss

of office. Mr. Gray continues to be employed by the Group

as its President & Chief Financial Officer.

No payments for loss of office were made during the year.

EXECUTIVE DIRECTORS SERVING AS

NON-EXECUTIVE DIRECTORS OF

OTHER COMPANIES

During the year none of the Executive Directors served as a

Non-Executive Director of any other company in respect of

which any Board-related remuneration was received.

164	Diversified Energy Company PLC Annual Report and Form 20-F2023

PERFORMANCE GRAPH AND CEO REMUNERATION TABLE

The Directors’ Remuneration Report Regulations 2002 require a line graph showing the TSR on a holding of shares in the

Group since admission to the Premium Segment of the Main Market of the LSE to the most recent financial year end following

such admission, as well as the TSR for a hypothetical holding of shares in a broad equity market index for the same period. The

Group was admitted to the Main Market on May 18, 2020 and the graph below covers that period, comparing the Group’s TSR

to that of the FTSE 250 (excluding Investment Trusts), an index of which the Group is a constituent. The committee is satisfied

that the CEO’s remuneration is supported by the TSR performance data presented below.

TOTAL SHAREHOLDER RETURN

Rebased at 100 on May 18, 2020

03_426107-1_line total shareholder return.jpg

Source: Datastream (a Refintiv product)

The table below details certain elements of the CEO’s remuneration over the same period as presented in the TSR Index graph:

(In Thousands)
Year	CEO	Single Figure of Total<br><br>Remuneration	Annual Bonus Pay-Out<br><br>Against Maximum %	Long-Term Incentive<br><br>Vesting Rates Against<br><br>Maximum Opportunity %
2023	Rusty Hutson, Jr.	$2,060	63%	40%
2022	Rusty Hutson, Jr.	$5,871	85%	71%
2021	Rusty Hutson, Jr.	$2,195	85%	45%
2020	Rusty Hutson, Jr.	$2,307	94%	100%

ANNUAL CHANGE IN REMUNERATION OF EACH DIRECTOR COMPARED TO EMPLOYEES

The table below presents the year-on-year (2021-2023) percentage change in remuneration for each Director and all

employees of the Group and its subsidiaries.

	% Change from 2022 to<br><br>2023			% Change from 2021 to<br><br>2022			% Change from 2020 to<br><br>2021			% Change from 2019 to<br><br>2020
Name	Salary/<br><br>Fee	Annual<br><br>Bonus	Taxable<br><br>Benefits	Salary/<br><br>Fee	Annual<br><br>Bonus	Taxable<br><br>Benefits	Salary/<br><br>Fee	Annual<br><br>Bonus	Taxable<br><br>Benefits	Salary/<br><br>Fee	Annual<br><br>Bonus	Taxable<br><br>Benefits
Rusty Hutson, Jr.	4%	(23%)	—%	4%	21%	20%	3%	(7%)	400%	59%	55%	—%
Bradley G. Gray(a)	4%	(45%)	(8%)	3%	3%	—%	3%	(7%)	(14%)	19%	15%	56%
David E. Johnson	8%	—%	—%	19%	—%	—%	3%	—%	—%	66%	—%	—%
Martin K. Thomas	7%	—%	—%	14%	—%	—%	2%	—%	—%	27%	—%	—%
David J. Turner, Jr.(b)	8%	—%	—%	16%	—%	—%	3%	—%	—%	132%	—%	—%
Sandra M. Stash(c)	8%	—%	—%	14%	—%	—%	2%	—%	—%	520%	—%	—%
Kathryn Z. Klaber(d)	100%	—%	—%	—%	—%	—%	2%	—%	—%	—%	—%	—%
Sylvia Kerrigan(e)	33%	—%	—%	445%	—%	—%	100%	—%	—%	—%	—%	—%
All employees,<br><br>excluding Directors	4%	4%	—%	5%	5%	—%	11%	(2%)	—%	4%	4%	—%
Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	165
---	---	---	---	---

(a)Mr. Gray was a Director until September 15, 2023. Mr. Gray’s fixed pay compensation for the year ended December 31, 2023 is for the period

he was a Director.

(b)David J. Turner, Jr. was appointed to the Board on May 27, 2019.

(c)Sandra M. Stash was appointed to the Board on October 21, 2019.

(d)Kathryn Z. Klaber was appointed to the Board on January 1, 2023.

(e)Sylvia Kerrigan was appointed to the Board on October 11, 2021.

CEO TO EMPLOYEE PAY RATIO

Although the Group does not have 250 full time equivalent UK employees, the Group provides a CEO to employee pay ratio on

a voluntary basis below. The average CEO to employee pay ratio improved this year. The committee is satisfied that the CEO

to employee pay ratio is consistent with the Group’s overall aim to ensure its employees are rewarded fairly and competitively

for their contributions.

Year	Method	25th Percentile Pay Ratio	Average Pay Ratio	75th Percentile Pay Ratio
2023	Option A	25:1	17:1	16:1
2022	Option A	28:1	19:1	17:1
2021	Option A	44:1	30:1	28:1

Notes to the CEO to employee pay ratio:

1.We have used Option A with figures as of December 31, 2023, following guidance that this is the preferred approach of

some proxy advisors and institutional shareholders. Option A captures all relevant pay and benefits for all employees.

2.The ratios shown are representative of the 25th percentile, median and 75th percentile pay for all employees within the

Group during the 2023 calendar year.

3.The CEO pay ratio is based on the taxable income for all employees employed for the duration of calendar year 2023 as

reported on U.S. IRS Form W-2, Wage and Tax Statement.

RELATIVE IMPORTANCE OF SPEND ON PAY

The table below details the change in total employee pay between 2022 and 2023, compared with distributions to

shareholders by way of dividend or share buybacks.

(In thousands)	2023	2022	% Change
Total gross employee pay	$124,834	$113,267	10%
Dividends/share buybacks	179,089	178,146	1%

The number of employees as of December 31, 2023 was 1,603, as compared to 1,582 employees as of December 31, 2022.

Statement of Voting at General Meeting

The following table shows the results of the binding Remuneration Policy vote at the April 26, 2022 AGM and the advisory

Directors’ Remuneration Report vote at the May 2, 2023 AGM.

	(Binding Vote)		(Advisory Vote)
	Approval of the Directors’<br><br>Remuneration Policy		Director Remuneration Report
	Total number of<br><br>votes	% of votes cast	Total number of<br><br>votes	% of votes cast
For	27,783,031	83%	21,839,879	62%
Against	5,793,079	17%	13,566,740	38%
Votes withheld	1,164,541		910,347

Shareholder Engagement

At the 2023 AGM, the committee was disappointed that the

Directors’ remuneration report was passed with 62%

support from shareholders. Following the AGM, the Group

consulted and engaged with a number of shareholders

including those who voted against the resolutions to better

understand their concerns. The Board is thankful to the

shareholders for sharing their views and understand that

the negative vote was principally related to the specific,

one-off issue of the grant price used for the 2020 LTIP

awards and the resulting remuneration outcomes.

The longstanding approach to the calculation of the share

price used to set the number of shares subject to an LTIP

award is included in the shareholder approved Directors’

Remuneration Policy as the average share price for the five

days following the announcement of the Group’s results for

the previous financial year. This was the approach followed

for the 2020 LTIP awards and all other recent awards.

166	Diversified Energy Company PLC Annual Report and Form 20-F2023

The committee did not consider it appropriate to apply a

reduction to the vesting outcome as this was assessed to

be commensurate with the performance over the period,

which included the ROE and relative TSR targets being met

in full. The committee was mindful that any downward

adjustment could have risked damaging the integrity of the

LTIP and was also conscious that no reciprocal upward

adjustment would be made in a year when the share price

peaked at the time of grant, resulting in a reduced number

of shares being awarded. The vested awards are also

subject to a two-year holding period, so the value

subsequently realised by the executive directors will be

subject to market movements over this period.

The dialogue with the shareholders highlighted that there

remains strong support for the Group's remuneration policy

which was approved by shareholders at the 2022 AGM. The

Group's Remuneration Committee has discussed the

feedback received in detail with the Board and will maintain

dialogue with shareholders on matters related to executive

remuneration. The committee will review with shareholders

the evolving needs of the business in advance of the

cyclical renewal of our Directors’ Remuneration Policy

in 2025.

IMPLEMENTATION OF POLICY FOR 2024

Base Salary

The Executive Director’s base salary for 2024 will be

as follows:

—Rusty Hutson, Jr: $779,834

For 2024, the committee approved an increase to the

CEO’s salary by 4%. This compares to increases across the

Group ranging from 0% to 10% based on performance, with

an average of 4%. It is anticipated that increases for the

remainder of the life of the policy will be in-line with the

range of the workforce.

Pension

The Executive Director does not receive a

pension provision.

Benefits

The Executive Director receives life insurance and

automobile benefits, and matching contributions under the

Group’s 401(k) plan. There is no current intention to

introduce additional benefits in 2024.

Annual Bonus

The overall 2024 bonus plan maximum will be 175% of base

salary for Rusty Hutson, Jr.

The bonus will be based on a range of targets relating to

adjusted EBITDA per share (50%), cash cost per Mcfe

(20%), and ESG/EHS (30%).

Due to issues of commercial sensitivity, we do not believe it

is in shareholders’ interests to disclose any further details of

these targets on a prospective basis. However, the

committee is committed to adhering to principles of

transparency in terms of retrospective annual bonus target

disclosure and will, therefore, provide appropriate and

relevant levels of disclosure for the bonus targets applied to

the 2024 bonus (and performance against these targets) in

next year’s Director’s Remuneration Report.

Bonuses are payable in cash for outcomes up to 100% of

base salary, with any outcomes above this level made as

awards of deferred shares or cash which vests after

one year.

Long-Term Incentives

Performance Share Awards will be made in 2024 to Rusty Hutson, Jr. with shares worth 325% of salary. The share price used

to calculate the number of shares subject to the award will be based on the average share price over the five-day period

commencing on the date that the Group issues its final 2023 results. These awards will vest three years after grant, and will

also be subject to a further two-year holding period after the initial three-year period to vesting.

The performance conditions for the Performance Share Award will be a mix of Return on Equity (40%), Absolute TSR (30%),

Relative TSR (10%) and Emissions (20%) targets measured over three years as described below. These are measures which

encourage the generation of sustainable long-term returns to shareholders. When determining the level of vesting the

committee will also consider that the outcome of the measurement reflects the underlying performance or financial health of

the Group.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information
RETURN ON EQUITY (40% OF TOTAL AWARD)		ABSOLUTE TSR (30% OF TOTAL AWARD)
---	---	---	---
Three-Year Average ROE	% of that Part of the Award<br><br>that Vests	Three-Year Absolute TSR	% of that Part of the Award<br><br>that Vests
Below 15% per annum	—%	Below 10% per annum	—%
15% per annum	15%	10% per annum	15%
25% per annum or above	100%	20% per annum or above	100%
15% to 25% per annum	Pro rata straight-line between<br><br>15% and 100%	10% to 20% per annum	Pro rata straight-line between<br><br>15% and 100%
RELATIVE TSR (10% OF TOTAL AWARD)		EMISSIONS (20% OF TOTAL AWARD)
Three-Year TSR v FTSE<br><br>250	% of that Part of the Award<br><br>that Vests	Emissions over Three Years	% of that Part of the Award<br><br>that Vests
Below median	—%	Below 5% Methane Intensity<br><br>Reduction	—%
Median	15%	5% Methane Intensity<br><br>Reduction	15%
Upper quartile or above	100%	15% Methane Intensity<br><br>Reduction	100%
Median to upper quartile	Pro rata straight-line between<br><br>15% and 100%	5% to 15% Methane Intensity<br><br>Reduction	Pro rata straight-line between<br><br>15% and 100%

NON-EXECUTIVE DIRECTORS’ FEES

David E. Johnson will receive an annual fee of £174,000 (or $215,760) as Chairman. Each Non-Executive Director receives a

base annual fee of £105,000 (or $133,350), with additional fees as noted below (table in thousands, except rates).

		USD
David J. Turner, Jr.(a)	135	$167
Sandra M. Stash(b)	125	155
Sylvia Kerrigan(c)	135	167
David E. Johnson	174	216
Martin K. Thomas(d)	125	155
Kathryn Z. Klaber(e)	125	155
Total	819	$1,015

All values are in British Pounds.

(a)Includes Audit & Risk Committee Chair fee of £30,000 (or $37,200).

(b)Includes Sustainability & Safety Committee Chair fee of £20,000 (or $24,800).

(c)Includes Senior Independent Director fee of £10,000 (or $12,400) and Remuneration Committee Chair fee of £20,000 (or $24,800).

(d)Includes Vice Chair fee of £20,000 (or $24,800).

(e)Includes Nomination & Governance Committee Chair fee of £20,000 (or $24,800).

Sylvia Kerrigan

Chair of the Remuneration Committee

March 19, 2024

“
The Remuneration Committee is focused on ensuring that remuneration is<br><br>designed to emphasize "pay for performance”
168	Diversified Energy Company PLC Annual Report and Form 20-F2023
---	---

The Sustainability & Safety

Committee’s Report

Sandra M. Stash<br><br>(64)<br><br>Independent Non-Executive<br><br>Director (Chair)<br><br>Strength:<br><br>Industry<br><br>Independence from:<br><br>Management & Other<br><br>interests	David E. Johnson<br><br>(63)<br><br>Non-Executive Chairman,<br><br>Independent upon<br><br>Appointment<br><br>Strength:<br><br>Finance<br><br>Independence from:<br><br>Management & Other<br><br>interests	Kathryn Z. Klaber<br><br>(58)<br><br>Independent Non-<br><br>Executive Director (as of<br><br>1/1/23)<br><br>Strength:<br><br>Regulatory,<br><br>Sustainability<br><br>Independence from:<br><br>Management<br><br>& Other Interests	Bradley G. Gray<br><br>(55)<br><br>President<br><br>& Chief Financial Officer<br><br>(Executive Director and<br><br>committee member until<br><br>9/15/23)<br><br>Strength:<br><br>Industry, Finance<br><br>Independence from:<br><br>Other Interests

Key Objective

The Sustainability & Safety Committee acts on behalf of the

Board and the shareholders to oversee the practices and

performance of the Group with respect to health and

safety, business ethics, conduct and responsibility, social

affairs, the environment (including climate) and broader

sustainability issues. As part of the Group’s overall

sustainability actions, the committee oversees the Group’s

climate scenario analysis planning and performance against

goals and ensures adherence to the recommended TCFD

disclosures for use by investors, lenders, insurers and

other stakeholders.

Overview

The committee assesses the Group’s overall sustainability

performance and provides input into the Annual Report &

Form 20-F, the Sustainability Report and other disclosures

on sustainability. It also advises the Remuneration

Committee on metrics relating to sustainable development,

GHG and other emissions, regulatory compliance, diversity

and inclusion, community engagement and other

social goals, as well as health and safety that apply to

executive remuneration.

The committee reviews the Group’s Sustainability and

Safety plans and reviews execution of the plan and audit

outcomes. In addition, the committee reviews and considers

external stakeholder perspectives in relation to the Group’s

business, and reviews how the Group addresses issues of

stakeholder concern that could affect its reputation and

license to operate.

The overall accountability for sustainability and safety is

with the President and Chief Financial Officer and the

Senior Leadership Team, including the Executive Vice

President of Operations, Chief Human Resources Officer,

the Senior Vice President of EHS and the Senior Vice

President of Sustainability, who are assisted by the

EHS team.

Key Matters Discussed by

the Committee

MAIN ACCOMPLISHMENTS OVER THE

COURSE OF 2023

—Established and reviewed the Group’s sustainability and

safety strategies and assessed the Group’s performance;

—Engaged with the leadership of the Group and monitored

progress against the Group’s methane emission intensity

reduction targets and accelerated commitment to

achieve net zero absolute Scope 1 and 2 GHG emissions

by 2040;

—Continued the review program to align executive

management remuneration with key safety and

sustainability performance indicators and metrics,

including factoring GHG reductions into long-term

incentives, that has been communicated to the

Remuneration Committee;

—Engaged with the leadership of the Group to understand

the diversity profile of the Group’s workforce;

—Engaged with a consortium of advisers, comprising

leading global environmental consultancies and other

strategic advisers, and continued to implement the

recommendations set forth by the TCFD with the

exception of reporting on Scope 3; and

—Reviewed the Group’s sustainability related

communications, including the composition and

approval of the Group’s 2022 Sustainability Report

and preparation for issuance of the 2023

Sustainability Report.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	169

Committee Activities by

Focus Area

During 2023, the committee met regularly to review and

discuss a range of prioritized topics. These topics included

(i) the safe and responsible operation of the Group’s

upstream and midstream assets; (ii) environmental

protection and conservation activities; (iii) the Group’s

approach to diversity and inclusion; (iv) the Group’s

approach to managing climate risk, (v) the Group’s

emissions reduction capital programs; and (vi) the Group’s

plugging business. The committee also focused on

the following:

PROCESS SAFETY

—The Executive Vice President of Operations presented an

overview of the Group’s process safety approach and

identification of high-risk facility performance, as well as

comparable performance benchmarking against

industry peers.

CORPORATE SCORECARD

METRICS OVERSIGHT

—The committee reviewed the quantitative and qualitative

drivers impacting the Group’s personnel safety,

emissions management, environmental performance,

and asset retirement metrics that support

performance analysis.

—The committee reviewed and discussed the Group’s

increased incident rate for the year, which were

attributable in part to short service employees with less

than one year of service under Diversified’s safety

culture. The Group is seeking to address this increase

through a new Safety Strategy Committee which was

created to identify and advance specific areas for

improvement and accountability.

SUSTAINABILITY RATING AGENCY

SCORECARD

—The committee reviewed the Group’s various third-party

sustainability rating scores, including analysis of the

process and review of scorecards to determine targeted

areas of improvement.

CLIMATE RISK

—The committee engaged the support of industry and

internationally recognized consultants and advisers to

help the Group update its climate scenario analysis and

advance its work on climate governance, strategy, risk

management and metrics as set forth under the TCFD.

The committee oversaw the Group’s engagement with

the GHG emissions inventory and associated scenario

analyses and remains actively engaged in setting targets

in accordance with the recommendations. The

committee has considered the relevance of material

climate-related matters, including the physical and

transition risks of climate change, when preparing this

Annual Report & Form 20-F. Further information can be

found in the TCFD and Climate-Related Risks sections

within this Annual Report & Form 20-F.

ACQUISITION DUE DILIGENCE

—Adding emphasis to its oversight of the Group’s

investment activities, the committee stayed apprised of

the progress and assessment of the Group’s emissions

screening efforts to aid in its assessment that proposed

acquisitions and other capital investments have on its

consolidated GHG emissions profile and associated

publicly stated targets.

EMISSION REDUCTION INITIATIVES

—The committee engaged in strategic discussions with

senior management regarding its capital program for

emissions reductions, including regular updates on the

deployment and success of handheld detection

equipment and aerial LiDAR surveys, as well as the

replacement of pneumatic valves. The Group also

advanced its Marginal Abatement Cost Curve (MACC)

analysis that will help to inform reduction emissions

planning in future years.

OIL & GAS METHANE PARTNERSHIP

RECOGNITION

—The committee supported the Group’s efforts in

achieving the OGMP 2.0 Gold Standard Pathway

designation in recognition of the Group’s demonstrated

commitment to set aggressive and achievable multi-year

plans designed to accurately measure and transparently

report its efforts to reduce methane emissions.

AREAS OF FOCUS FOR 2024 AND BEYOND

—Support the Group in meeting increasing sustainability

oversight, reporting and disclosure expectations of the

Group’s stakeholders, including short, medium and

long-term quantitative metrics and qualitative objectives

tied to executive compensation for reducing GHG

emissions (including formalizing a roadmap to be net

zero absolute Scope 1 and 2 GHG emissions by 2040);

—Support the Group in its diversity and

inclusion aspirations;

—Support management with effective oversight and

advice as the Group executes and reports on the

recommendations of the TCFD work and MACC analysis,

serving to further integrate climate considerations into

business planning and strategies; and

—Provide advice and guidance on potential further EHS

enhancements and reporting metrics, including an

increased focus on safety, well abandonment, water

management and biodiversity; and

COMMITTEE EFFECTIVENESS

—The committee performed a critical analysis internal

review and evaluation on itself, as part of its annual

self-review process. No significant areas of concern

were raised.

170	Diversified Energy Company PLC Annual Report and Form 20-F2023

Membership

The formation of a Sustainability & Safety Committee is not

a recommendation under the current UK Corporate

Governance Code. The Group and the Board, however,

consider such a committee to be an imperative given the

operational footprint of the business and the evolving

operational, regulatory, social and investment markets

within which the Group operates.

The committee is currently comprised of the Non-Executive

Chairman and two Independent Non-Executive Directors:

Sandra M. Stash, the Sustainability & Safety Committee

Chair, David E. Johnson and Kathryn Z. Klaber. Ms. Klaber

was appointed to the committee as an Independent Non-

Executive Director as of January 1, 2023. Additionally,

Bradley G. Gray stepped down from the committee on

September 15, 2023 concurrent with his departure from the

Board and appointment as the Group’s President and Chief

Financial Officer. Benjamin Sullivan, Senior Executive

Vice President, Chief Legal & Risk Officer and Corporate

Secretary acts as Secretary to the committee.

The committee has extensive and relevant experience in

EHS and social matters through their other business

activities. For one example, Ms. Stash formerly served as

Executive Vice President — Safety, Operations, Engineering,

and External Affairs for Tullow Oil until her retirement.

Meetings and Attendance

The Sustainability & Safety Committee met five times

during 2023 and one time thus far in 2024. The committee

also regularly meets in private executive session at the end

of its committee meetings, without management present, to

ensure that points of common concern are identified and

that priorities for future attention by the committee are

agreed upon. The Chair of the committee keeps in close

contact with the Chief Legal & Risk Officer, the Senior Vice

President of Sustainability, the Senior Vice President of EHS

and the EHS team and external consultants between

meetings of the committee. For committee meeting

attendance for each Director see the Directors’ Report

within this Annual Report & Form 20-F.

The list below details the members of the Senior Leadership

Team who were invited to attend meetings as appropriate

during the calendar year.

—Bradley G. Gray (President and Chief Financial Officer)

—Benjamin Sullivan (Senior Executive Vice President, Chief

Legal & Risk Officer, and Corporate Secretary)

—Maverick Bentley (Executive Vice President of

Operations)

—Paul Espenan (Senior Vice President of Environmental,

Health and Safety)

—Teresa Odom (Senior Vice President of Sustainability)

—Mark Kirkendall (Executive Vice President, Chief Human

Resources Officer)

Responsibilities and Terms

of Reference

The committee’s main duties are:

—Overseeing the development and implementation by

management of policies, compliance systems,

and monitoring processes to ensure compliance by the

Group with applicable legislation, rules and regulations;

—Establishing with management long-term climate,

environmental and social sustainability and, EHS goals

and evaluating the Group’s progress against those goals;

—Advising management on implementing, maintaining and

improving environmental and social sustainability and

EHS strategies, implementation of which creates value

consistent with long-term preservation and enhancement

of shareholder value;

—Considering and advising management of emerging

environmental and social sustainability issues that may

affect the business, performance or reputation of the

Group and makes recommendations, as appropriate, on

how management can address such issues;

—Monitoring the Group’s risk management processes

related to environmental and social sustainability and

EHS with particular attention to managing and reducing

environmental risks and impacts; and

—Reviewing handling of incident reports, results of

investigations into material events, findings from

environmental and social sustainability and EHS audits

and the action plans proposed pursuant to

those findings.

The committee has formal terms of reference which can be

viewed on the Group’s website at www.div.energy.

Sandra M. Stash

Chair of the Sustainability & Safety Committee

March 19, 2024

“
The committee has extensive<br><br>and relevant experience in EHS<br><br>matters through their other<br><br>business activities.
Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	171
---	---	---	---	---

Group

Financial

Statements

173	Report of Independent Registered Public Accounting<br><br>Firm (PCAOB ID238)
175	Consolidated Statement of Comprehensive Income
176	Consolidated Statement of Financial Position
177	Consolidated Statement of Changes in Equity
178	Consolidated Statement of Cash Flows
179	Notes to the Group Financial Statements
172	Diversified Energy Company PLC Annual Report and Form 20-F2023
---	---

Report of Independent Registered Public Accounting Firm

To the Board of Directors and Shareholders of Diversified Energy Company Plc

Opinion on the Financial Statements

We have audited the accompanying consolidated statement of financial position of Diversified Energy Company

Plc and its subsidiaries (the "Company") as of December 31, 2023 and 2022, and the related consolidated

statements of comprehensive income, of changes in equity, and of cash flows for each of the three years in the

period ended December 31, 2023, including the related notes (collectively referred to as the "consolidated financial

statements"). In our opinion, the consolidated financial statements present fairly, in all material respects, the

financial position of the Company as of December 31, 2023 and 2022, and the results of its operations and its cash

flows for each of the three years in the period ended December 31, 2023 in conformity with International Financial

Reporting Standards as issued by the International Accounting Standards Board.

Basis for Opinion

These consolidated financial statements are the responsibility of the Company's management. Our responsibility is

to express an opinion on the Company's consolidated financial statements based on our audits. We are a public

accounting firm registered with the Public Company Accounting Oversight Board (United States) (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 of these consolidated financial statements in accordance with the standards of the

PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about

whether the consolidated financial statements are free of material misstatement, whether due to error or fraud.

Our audits included performing procedures to assess the risks of material misstatement of the consolidated

financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such

procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the

consolidated financial statements. Our audits also included evaluating the accounting principles used and

significant estimates made by management, as well as evaluating the overall presentation of the consolidated

financial statements. We believe that our audits provide a reasonable basis for our opinion.

Critical Audit Matters

The critical audit matter communicated below is a matter arising from the current period audit of the consolidated

financial statements that was communicated or required to be communicated to the audit committee and that (i)

relates to accounts or disclosures that are material to the consolidated financial statements and (ii) involved our

especially challenging, subjective, or complex judgments. The communication of critical audit matters does not

alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by

communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the

accounts or disclosures to which it relates.

The Impact of Proved Natural Gas, Oil, and Natural Gas Liquids (NGL) Reserves on Natural Gas and Oil

Properties, Net

As described in Notes 3, 4 and 10 to the consolidated financial statements, the Company's natural gas and oil

properties, net balance was $2.50 billion as of December 31, 2023, and the related depletion expense for the year

ended December 31, 2023 was $168 million. Natural gas and oil activities are accounted for using the principles of

the successful efforts method of accounting. Costs incurred to purchase, lease, or otherwise acquire a property are

capitalized when incurred. Proved natural gas, oil and NGL reserve volumes are used as the basis to calculate unit-

of-production depletion rates. For the year ended December 31, 2023, pre-tax impairment charges of $42 million

were recognized. In estimating proved natural gas, oil and NGL reserves, management relies on interpretations

and judgment of available geological, geophysical, engineering and production data, as well as the use of certain

economic assumptions such as commodity pricing. Additional assumptions include operating expenses, capital

expenditures, and taxes. As disclosed by management, the Company's internal staff of petroleum engineers and

geoscience professionals work closely with the independent reserve engineers (together referred to as

"management's specialists").

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	173

The principal considerations for our determination that performing procedures relating to the impact of proved

natural gas, oil and NGL reserves on proved natural gas and oil properties, net is a critical audit matter are (i.) the

significant judgment by management, including the use of management's specialists, when developing the

estimates of proved natural gas, oil and NGL reserve volumes, as the reserve volumes are based on engineering

assumptions and methods and (ii) a high degree of auditor judgment, subjectivity, and effort in performing

procedures and evaluating audit evidence obtained related to the data, methods, and assumptions used by

management and its specialists in developing the estimates of proved natural gas, oil and NGL reserve volumes

and the assumptions applied to commodity pricing and operating expenses applied to the impairment assessment.

Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming

our overall opinion on the consolidated financial statements. The work of management's specialists was used in

performing the procedures to evaluate the reasonableness of the proved natural gas, oil and NGL reserve volumes

and the impairment assessment. As a basis for using this work, the specialists' qualifications were understood and

the Company's relationship with the specialists was assessed. The procedures performed also included evaluating

the methods and assumptions used by the specialists, testing the completeness and accuracy of the data used by

the specialists, and evaluating the specialists' findings. These procedures also included, among others, testing the

completeness and accuracy of the underlying data related to commodity pricing and operating expenses applied to

the impairment assessment. Additionally, these procedures included evaluating whether the assumptions applied

to the data related to commodity pricing and operating expenses that were used in developing the estimate of

proved natural gas, oil and NGL reserve volumes were reasonable considering the past performance of the

Company.

/s/ PricewaterhouseCoopers LLP

Birmingham, Alabama

March 19, 2024

We have served as the Company’s auditor since 2020.

174	Diversified Energy Company PLC Annual Report and Form 20-F2023

Consolidated Statement of

Comprehensive Income

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

		Year Ended
	Notes	December 31, 2023	December 31, 2022	December 31, 2021
Revenue	6	$868,263	$1,919,349	$1,007,561
Operating expenses	7	(440,562)	(445,893)	(291,213)
Depreciation, depletion and amortization	7	(224,546)	(222,257)	(167,644)
Gross profit		$203,155	$1,251,199	$548,704
General and administrative expenses	7	(119,722)	(170,735)	(102,326)
Allowance for expected credit losses		(8,478)	—	4,265
Gain (loss) on natural gas and oil properties and<br><br>equipment	10,11	24,146	2,379	(901)
Gain (loss) on sale of equity interest	5	18,440	—	—
Unrealized gain (loss) on investment	5	4,610	—	—
Gain (loss) on derivative financial instruments	13	1,080,516	(1,758,693)	(974,878)
Gain on bargain purchases	5	—	4,447	58,072
Impairment of proved properties	10	(41,616)	—	—
Operating profit (loss)		$1,161,051	$(671,403)	$(467,064)
Finance costs	21	(134,166)	(100,799)	(50,628)
Accretion of asset retirement obligation	19	(26,926)	(27,569)	(24,396)
Other income (expense)		385	269	(8,812)
Income (loss) before taxation		$1,000,344	$(799,502)	$(550,900)
Income tax benefit (expenses)	8	(240,643)	178,904	225,694
Net income (loss)		$759,701	$(620,598)	$(325,206)
Other comprehensive income (loss)		(270)	940	51
Total comprehensive income (loss)		$759,431	$(619,658)	$(325,155)
Net income (loss) attributable to:
Diversified Energy Company PLC		$758,018	$(625,410)	$(325,509)
Non-controlling interest		1,683	4,812	303
Net income (loss)		$759,701	$(620,598)	$(325,206)
Earnings (loss) per share attributable to Diversified<br><br>Energy Company PLC
Weighted average shares outstanding - basic	9	47,165	42,204	39,677
Weighted average shares outstanding - diluted	9	47,514	42,204	39,677
Earnings (loss) per share - basic	9	$16.07	$(14.82)	$(8.20)
Earnings (loss) per share - diluted	9	$15.95	$(14.82)	$(8.20)

The notes on pages 179 to 226 are an integral part of the Group Financial Statements.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	175

Consolidated Statement of

Financial Position

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

	Notes	December 31, 2023	December 31, 2022
ASSETS
Non-current assets:
Natural gas and oil properties, net	10	$2,490,375	$2,555,808
Property, plant and equipment, net	11	456,208	462,860
Intangible assets	12	19,351	21,098
Restricted cash	3	25,057	47,497
Derivative financial instruments	13	24,401	13,936
Deferred tax assets	8	144,860	371,156
Other non-current assets	15	9,172	4,351
Total non-current assets		$3,169,424	$3,476,706
Current assets:
Trade receivables, net	14	190,207	296,781
Cash and cash equivalents	3	3,753	7,329
Restricted cash	3	11,195	7,891
Derivative financial instruments	13	87,659	27,739
Other current assets	15	11,784	14,482
Total current assets		$304,598	$354,222
Total assets		$3,474,022	$3,830,928
EQUITY AND LIABILITIES
Shareholders' equity:
Share capital	16	$12,897	$11,503
Share premium	16	1,208,192	1,052,959
Treasury reserve		(102,470)	(100,828)
Share based payment and other reserves		14,442	17,650
Retained earnings (accumulated deficit)		(547,255)	(1,133,972)
Equity attributable to owners of the parent:		585,806	(152,688)
Non-controlling interests	5	12,604	14,964
Total equity		$598,410	$(137,724)
Non-current liabilities:
Asset retirement obligations	19	$501,246	$452,554
Leases	20	20,559	19,569
Borrowings	21	1,075,805	1,169,233
Deferred tax liability	8	13,654	12,490
Derivative financial instruments	13	623,684	1,177,801
Other non-current liabilities	23	2,224	5,375
Total non-current liabilities		$2,237,172	$2,837,022
Current liabilities:
Trade and other payables	22	$53,490	$93,764
Taxes payable		50,226	41,907
Leases	20	10,563	9,293
Borrowings	21	200,822	271,096
Derivative financial instruments	13	45,836	293,840
Other current liabilities	23	277,503	421,730
Total current liabilities		$638,440	$1,131,630
Total liabilities		$2,875,612	$3,968,652
Total equity and liabilities		$3,474,022	$3,830,928	The notes on pages 179 to 226 are an integral part of the Group Financial Statements.<br><br>The Group Financial Statements were approved and authorized for issue by the Board on March 19,<br><br>2024 and were signed on its behalf by:	<br><br>David E. Johnson<br><br>Chairman of the Board<br><br>March 19, 2024
---	---
176	Diversified Energy Company PLC Annual Report and Form 20-F2023
---	---

Consolidated Statement of

Changes in Equity

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

	Notes	Share<br><br>Capital	Share<br><br>Premium	Treasury<br><br>Reserve	Share<br><br>Based<br><br>Payment<br><br>and Other<br><br>Reserves	Retained<br><br>Earnings<br><br>(Accumulated<br><br>Deficit)	Equity<br><br>Attributable<br><br>to Owners of<br><br>the Parent	Non-<br><br>Controlling<br><br>Interest	Total Equity
Balance as of January 1, 2021		$9,520	$841,159	$(68,537)	$8,797	$95,719	$886,658	$—	$886,658
Net income (loss)		—	—	—	—	(325,509)	(325,509)	303	(325,206)
Other comprehensive income<br><br>(loss)		—	—	—	—	51	51	—	51
Total comprehensive income<br><br>(loss)		$—	$—	$—	$—	$(325,458)	$(325,458)	$303	$(325,155)
Non-controlling interest in<br><br>acquired assets	5	—	—	—	—	—	—	16,238	16,238
Issuance of share capital<br><br>(equity placement)	16	2,044	211,800	—	—	—	213,844	—	213,844
Issuance of share capital<br><br>(equity compensation)		7	—	—	6,788	(2,762)	4,033	—	4,033
Dividends	18	—	—	—	—	(130,239)	(130,239)	—	(130,239)
Cancellation of warrants	16	—	—	—	(1,429)	—	(1,429)	—	(1,429)
Transactions with shareholders		$2,051	$211,800	$—	$5,359	$(133,001)	$86,209	$16,238	$102,447
Balance as of December 31,<br><br>2021		$11,571	$1,052,959	$(68,537)	$14,156	$(362,740)	$647,409	$16,541	$663,950
Net income (loss)		—	—	—	—	(625,410)	(625,410)	4,812	(620,598)
Other comprehensive income<br><br>(loss)		—	—	—	—	940	940	—	940
Total comprehensive income<br><br>(loss)		$—	$—	$—	$—	$(624,470)	$(624,470)	$4,812	$(619,658)
Issuance of share capital<br><br>(settlement of warrants)	16	5	—	—	452	—	457	—	457
Issuance of share capital<br><br>(equity compensation)		7	—	—	5,682	(3,307)	2,382	—	2,382
Issuance of EBT shares<br><br>(equity compensation)	16	—	—	2,400	(2,400)	—	—	—	—
Repurchase of shares (EBT)	16	—	—	(22,931)	—	—	(22,931)	—	(22,931)
Repurchase of shares (share<br><br>buyback program)	16	(80)	—	(11,760)	80	—	(11,760)	—	(11,760)
Dividends	18	—	—	—	—	(143,455)	(143,455)	—	(143,455)
Distributions to non-<br><br>controlling interest owners		—	—	—	—	—	—	(6,389)	(6,389)
Cancellation of warrants	16	—	—	—	(320)	—	(320)	—	(320)
Transactions with shareholders		$(68)	$—	$(32,291)	$3,494	$(146,762)	$(175,627)	$(6,389)	$(182,016)
Balance as of December 31,<br><br>2022		$11,503	$1,052,959	$(100,828)	$17,650	$(1,133,972)	$(152,688)	$14,964	$(137,724)
Net Income (loss)		—	—	—	—	758,018	758,018	1,683	759,701
Other comprehensive income<br><br>(loss)		—	—	—	—	(270)	(270)	—	(270)
Total comprehensive income<br><br>(loss)		$—	$—	$—	$—	$757,748	$757,748	$1,683	$759,431
Issuance of share capital<br><br>(equity placement)	16	1,555	155,233	—	—	—	156,788	—	156,788
Issuance of share capital<br><br>(equity compensation)		—	—	—	6,037	(2,990)	3,047	—	3,047
Issuance of EBT shares<br><br>(equity compensation)	16	—	—	9,406	(9,406)	—	—	—	—
Repurchase of shares (share<br><br>buyback program)	16	(161)	—	(11,048)	161	—	(11,048)	—	(11,048)
Dividends	18	—	—	—	—	(168,041)	(168,041)	—	(168,041)
Distributions to non-<br><br>controlling interest owners		—	—	—	—	—	—	(4,043)	(4,043)
Transactions with shareholders		$1,394	$155,233	$(1,642)	$(3,208)	$(171,031)	$(19,254)	$(4,043)	$(23,297)
Balance as of December 31,<br><br>2023		$12,897	$1,208,192	$(102,470)	$14,442	$(547,255)	$585,806	$12,604	$598,410

The notes on pages 179 to 226 are an integral part of the Group Financial Statements.

177	Diversified Energy Company plc Annual Report and Form 20-F2023

Consolidated Statement of Cash Flows

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

		Year Ended
	Notes	December 31, 2023	December 31, 2022	December 31, 2021
Cash flows from operating activities:
Income (loss) after taxation		$759,701	$(620,598)	$(325,206)
Cash flows from operations reconciliation:
Depreciation, depletion and amortization	7	224,546	222,257	167,644
Accretion of asset retirement obligations	19	26,926	27,569	24,396
Impairment of proved properties	10	41,616	—	—
Income tax (benefit) expense	8	240,643	(178,904)	(225,694)
(Gain) loss on fair value adjustments of unsettled financial<br><br>instruments	13	(905,695)	861,457	652,465
Asset retirement costs	19	(5,961)	(4,889)	(2,879)
(Gain) loss on natural gas and oil properties and equipment	5,10,11	(24,146)	(2,379)	901
(Gain) loss on sale of equity interest	5	(18,440)	—	—
Unrealized (gain) loss on investment	5	(4,610)	—	—
Gain on bargain purchases	5	—	(4,447)	(58,072)
Finance costs	21	134,166	100,799	50,628
Revaluation of contingent consideration	24	—	—	8,963
Hedge modifications	13	26,686	(133,573)	(10,164)
Non-cash equity compensation	17	6,494	8,051	7,400
Working capital adjustments:
Change in trade receivables and other current assets		104,571	13,760	(126,957)
Change in other non-current assets		1,661	(580)	(556)
Change in trade and other payables and other current liabilities		(183,530)	132,349	162,486
Change in other non-current liabilities		(6,236)	(6,794)	5,707
Cash generated from operations		$418,392	$414,078	$331,062
Cash paid for income taxes		(8,260)	(26,314)	(10,880)
Net cash provided by operating activities		$410,132	$387,764	$320,182
Cash flows from investing activities:
Consideration for business acquisitions, net of cash acquired	5	$—	$(24,088)	$(286,804)
Consideration for asset acquisitions	5	(262,329)	(264,672)	(287,330)
Proceeds from divestitures	5	95,749	—	86,224
Payments associated with potential acquisitions	15	—	—	(25,002)
Acquisition related debt and hedge extinguishments	5, 13	—	—	(56,466)
Expenditures on natural gas and oil properties and equipment	10,11	(74,252)	(86,079)	(50,175)
Proceeds on disposals of natural gas and oil properties and<br><br>equipment	10,11	4,083	12,189	2,663
Deferred consideration payments		(2,620)	—	—
Contingent consideration payments	24	—	(23,807)	(10,822)
Net cash used in investing activities		$(239,369)	$(386,457)	$(627,712)
Cash flows from financing activities:
Repayment of borrowings	21	$(1,547,912)	$(2,139,686)	$(1,432,566)
Proceeds from borrowings	21	1,537,230	2,587,554	1,727,745
Cash paid for interest	21	(116,784)	(83,958)	(42,673)
Debt issuance costs	21	(13,776)	(34,234)	(10,255)
Decrease (increase) in restricted cash	3	11,792	(36,287)	1,838
Hedge modifications associated with ABS Notes	13, 21	(6,376)	(105,316)	—
Proceeds from equity issuance, net	16	156,788	—	213,844
Principal element of lease payments	20	(12,169)	(10,211)	(7,556)
Cancellation (settlement) of warrants, net	16	—	137	(1,429)
Dividends to shareholders	18	(168,041)	(143,455)	(130,239)
Distributions to non-controlling interest owners		(4,043)	(6,389)	—
Repurchase of shares by the EBT	16	—	(22,931)	—
Repurchase of shares	16	(11,048)	(11,760)	—
Net cash provided by (used in) financing activities		$(174,339)	$(6,536)	$318,709
Net change in cash and cash equivalents		(3,576)	(5,229)	11,179
Cash and cash equivalents, beginning of period		7,329	12,558	1,379
Cash and cash equivalents, end of period		$3,753	$7,329	$12,558

The notes on pages 179 to 226 are an integral part of the Group Financial Statements.

178	Diversified Energy Company plc Annual Report and Form 20-F2023

Notes to the Group Financial

Statements

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

INDEX TO THE NOTES TO THE GROUP FINANCIAL STATEMENTS

Note 1 – General InformationPage 179

Note 2 – Basis of Preparation Page ##

Note 3 – Significant Accounting PoliciesPage 182

Note 4–Significant Accounting Judgments and Estimates Page 187

Note 5–Acquisitions and DivestituresPage 189

Note 6–RevenuePage 193

Note 7–Expenses by NaturePage 194

Note 8–TaxationPage 196

Note 9–Earnings (Loss) Per SharePage 199

Note 10–Natural Gas and Oil PropertiesPage 200

Note 11–Property, Plant and EquipmentPage 201

Note 12–Intangible AssetsPage 202

Note 13 – Derivative Financial InstrumentsPage 204

Note 14 – Trade and Other Receivables Page 208

Note 15– Other Assets Page 209

Note 16–Share CapitalPage 209

Note 17–Non-Cash Share-Based CompensationPage 211

Note 18–DividendsPage 213

Note 19–Asset Retirement ObligationsPage 214

Note 20 – LeasesPage 215

Note 21–BorrowingsPage 216

Note 22–Trade and Other PayablesPage 221

Note 23–Other LiabilitiesPage 221

Note 24–Fair Value and Financial InstrumentsPage 222

Note 25 – Financial Risk Management Page 223

Note 26 – Contingencies Page 225

Note 27 – Related Party Transactions Page 226

Note 28 – Subsequent Events Page 226

NOTE 1 - GENERAL INFORMATION

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

Diversified Energy Company PLC (the “Parent” or “Company”), formerly Diversified Gas & Oil PLC, and its wholly owned

subsidiaries (the “Group”) is an independent energy company engaged in the production, transportation and marketing of

primarily natural gas related to its synergistic U.S. onshore upstream and midstream assets. The Group’s assets are located

within the Appalachian and Central basins of the U.S.

The Company was incorporated on July 31, 2014 in the United Kingdom and is registered in England and Wales under the

Companies Act 2006 as a public limited company under company number 09156132. The Group‘s registered office is located

at 4th floor Phoenix House, 1 Station Hill, Reading, Berkshire, RG1 1NB, UK.

In May 2020, the Company’s shares were admitted to trading on the LSE’s Main Market for listed securities under the ticker

“DEC”. In December 2023, the Company’s shares were admitted to trading on the New York Stock Exchange (“NYSE”) under

the ticker “DEC.” As of December 31, 2023, the principal trading market for the Company’s ordinary shares was the LSE.

NOTE 2 - BASIS OF PREPARATION

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

Basis of Preparation

The Group's consolidated financial statements (the “Group Financial Statements”) have been prepared in accordance with

International Financial Reporting Standards (“IFRS”) as issued by the International Accounting Standards Board (“IASB”). The

principal accounting policies set out below have been applied consistently throughout the year and are consistent with prior

year unless otherwise stated.

Unless otherwise stated, the Group Financial Statements are presented in U.S. Dollars, which is the Group’s subsidiaries’

functional currency and the currency of the primary economic environment in which the Group operates, and all values are

rounded to the nearest thousand dollars except per share and per unit amounts and where otherwise indicated.

Transactions in foreign currencies are translated into U.S. Dollars at the rate of exchange on the date of the transaction.

Monetary assets and liabilities denominated in foreign currencies are translated at the exchange rate at the date of the

Consolidated Statement of Financial Position. Where the Group’s subsidiaries have a different functional currency, their results

and financial position are translated into the presentation currency as follows:

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	179

—Assets and liabilities in the Consolidated Statement of Financial Position are translated at the closing rate

at the date of that Consolidated Statement of Financial Position;

—Income and expenses in the Consolidated Statement of Comprehensive Income are translated at average exchange rates

(unless this is not a reasonable approximation of the cumulative effect of the rates prevailing on the transaction dates, in

which case income and expenses are translated at the dates of the transactions); and

—All resulting exchange differences are reflected within other comprehensive income in the Consolidated Statement of

Comprehensive Income.

The Group Financial Statements have been prepared under the historical cost convention, as modified by the revaluation of

financial assets and liabilities (including derivative instruments) held at fair value through profit and loss or through other

comprehensive income.

Segment Reporting

The Group is an independent owner and operator of producing natural gas and oil wells with properties located in the states of

Tennessee, Kentucky, Virginia, West Virginia, Ohio, Pennsylvania, Oklahoma, Texas and Louisiana. The Group’s strategy is to

acquire long-life producing assets, efficiently operate those assets to generate free cash flow for shareholders and then to

retire assets safely and responsibly at the end of their useful life. The Group’s assets consist of natural gas and oil wells,

pipelines and a network of gathering lines and compression facilities which are complementary to the Group’s assets.

In accordance with IFRS the Group establishes segments on the basis on which those components of the Group are evaluated

regularly by the chief executive officer, DEC’s chief operating decision maker (“CODM”), when deciding how to allocate

resources and in assessing performance. When evaluating performance as well as when acquiring and managing assets the

CODM does so in a consolidated and complementary fashion to vertically integrate and improve margins. Accordingly, when

determining operating segments under IFRS 8, the Group has identified one reportable segment that produces and transports

natural gas, NGLs and oil in the U.S.

Going Concern

The Group Financial Statements have been prepared on the going concern basis, which contemplates the continuity of normal

business activity and the realization of assets and the settlement of liabilities in the normal course of business. The Directors

have reviewed the Group’s overall position and outlook and are of the opinion that the Group is sufficiently well funded to be

able to operate as a going concern for at least the next twelve months from the date of approval of this Annual Report & Form

20-F.

The Directors closely monitor and carefully manage the Group’s liquidity risk. Our financial outlook is assessed primarily

through the annual business planning process, however it is also carefully monitored on a monthly basis. This process includes

regular Board discussions, led by senior leadership, at which the current performance of, and outlook for, the Group are

assessed. The outputs from the business planning process include a set of key performance objectives, an assessment of the

Group’s primary risks, the anticipated operational outlook and a set of financial forecasts that consider the sources of funding

available to the Group (the “Base Plan”).

The Base Plan incorporates key assumptions which underpin the business planning process. These assumptions are as follows:

—Projected operating cash flows are calculated using a production profile which is consistent with current operating results

and decline rates;

—Assumes commodity prices are in line with the current forward curve which also considers basis differentials;

—Operating cost levels stay consistent with historical trends;

—The financial impact of our current hedging contracts in place for the assessment period, which represents approximately

83%, and 76% of total production volumes hedged for the years ending December 31, 2024 and 2025, respectively; and

—The scenario also includes the scheduled principal and interest payments on our current debt arrangements.

The Directors and management also consider various scenarios around the Base Plan that primarily reflect a more severe, but

plausible, downside impact of the principal risks, both individually and in the aggregate, as well as the additional capital

requirements that downside scenarios could place on us. These scenarios are as follows:

Scenario 1: Cyclically low gas prices for a year (Henry Hub prices of $1.50 per MMbtu before returning to strip pricing), which

have been historically observed in the market.

Scenario 2: Considered the impact of climate change by assuming a two week period of lost production in our East Texas/

Louisiana region, which is susceptible to hurricanes, due to a natural disaster (assumed to occur once in each year of the

assessment period).

Scenario 3: Considered the impact of climate change by assuming a two week period of lost production in our Appalachian

region (assumption of lost production in 25% of the total region), which is susceptible to flooding, due to a natural disaster

(assumed to occur once in each year of the assessment period).

Under these downside sensitivity scenarios, the Group continues to meet its working capital requirements, which primarily

consist of derivative liabilities that, when settled, will be funded utilizing the higher commodity revenues from which the

derivative liability was derived. The Group will also continue to meet the covenant requirements under its Credit Facility as well

as its other existing borrowing instruments.

180	Diversified Energy Company plc Annual Report and Form 20-F2023

The Directors and management consider the impact that these principal risks could, in certain circumstances, have on the

Group’s prospects within the assessment period, and accordingly appraise the opportunities to actively mitigate the risk of

these severe, but plausible, downside scenarios. In addition to its modelled downside going concern scenarios, the Board has

stress tested the model to determine the extent of downturn which would result in a breach of covenants. Assuming similar

levels of cash conversion as seen in 2023, a decline in production volume and pricing well in excess of that historically

experienced by the Group would need to persist throughout the going concern period for a covenant breach to occur, which is

considered very unlikely.

In addition to the scenarios above, the Directors also considered the current geopolitical environment and the inflationary

pressures that are currently impacting the U.S., which are being closely monitored by the Group. Notwithstanding the

modelling of specific hypothetical scenarios, the Group believes that the impact associated with these events will largely

continue to be reflected in commodity markets and will extend the volatility experienced in recent months. The Group

considers commodity price risk a principal risk and will continue to actively monitor and mitigate this risk through our hedging

program.

Based on the above, the Directors have reviewed the Group’s overall position and outlook and are of the opinion that the

Group is sufficiently funded to be able to operate as a going concern for the next twelve months from the date of approval of

the Group Financial Statements.

Prior Period Reclassifications and Changes in Presentation

Reclassifications in the Consolidated Statement of Financial Position

The Group reclassified $41,907 to “taxes payable” from “other current liabilities” in the accompanying 2022 Consolidated

Statement of Financial Position to conform to current year presentation.

Reclassifications in the Consolidated Statement of Cash Flows

The Group reclassified certain amounts in it prior year Consolidated Statement of Cash Flows to conform to its current period

presentation. These changes in classification do not affect net cash provided by (used in) financing activities previously

reported in the Consolidated Statement of Cash Flows.

The Group reclassified $1,022 and $1,050 in “principal element of lease payments” to “cash paid for interest” for the years

ended December 31, 2022 and 2021, respectively.

Basis of Consolidation

The Group Financial Statements for the year ended December 31, 2023 reflect the following corporate structure of the Group,

and its wholly owned subsidiaries:

—Diversified Energy Company PLC

(“DEC”) as well as its wholly

owned subsidiaries

—Diversified Gas & Oil Corporation

—Diversified Production LLC

—Diversified ABS Holdings LLC

—Diversified ABS LLC

—Diversified ABS Phase II

Holdings LLC

—Diversified ABS Phase II LLC

—Diversified ABS Phase III

Holdings LLC

—Diversified ABS Phase

III LLC

—Diversified ABS III

Upstream LLC

—Diversified ABS Phase III

Midstream LLC

—Diversified ABS Phase IV

Holdings LLC

—Diversified ABS Phase

IV LLC

—Diversified ABS Phase V

Holdings LLC

—Diversified ABS Phase

V LLC

—Diversified ABS V

Upstream LLC

—DP Bluegrass Holdings LLC

—DP Bluegrass LLC

—Chesapeake Granite

Wash Trust(a)

—BlueStone Natural

Resources II LLC

—Sooner State Joint ABS

Holdings LLC(b)

—Diversified ABS Phase VI

Holdings LLC

—Diversified ABS Phase VI

LLC

—Diversified ABS VI

Upstream LLC

—Oaktree ABS VI

Upstream LLC

—DP Lion Equity Holdco LLC(c)

—DP Lion HoldCo LLC(c)

—DP Vandalia Equity Holdco

LLC

—DP Vandalia Holdco LLC

—DP RBL Co LLC

—DP Legacy Central LLC

—Diversified Energy

Marketing LLC

—DP Tapstone Energy

Holdings LLC

—DP Legacy Tapstone LLC

—TGG Cotton Valley Assets, LLC

—Giant Land, LLC(d)

—Link Land LLC(d)

—Old Faithful Land LLC(d)

—Riverside Land LLC(d)

—Splendid Land LLC(d)

—DP Production Holdings II LLC

—Diversified Midstream LLC

—Cranberry Pipeline Corporation

—Coalfield Pipeline Company

—DM Bluebonnet LLC

—Black Bear Midstream

Holdings LLC

—Black Bear Midstream LLC

—Black Bear Liquids LLC

—Black Bear Liquids

Marketing LLC

—DM Pennsylvania Holdco LLC

—DGOC Holdings Sub III LLC

—Diversified Energy Group

LLC

—Diversified Energy Company

LLC

—Next LVL Energy, LLC

(a)Diversified Production, LLC holds 50.8% of the issued and outstanding common shares of Chesapeake Granite Wash Trust.

(b)Owned 51.25% by Diversified Production LLC.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	181

(c)Diversified Production, LLC holds 20% of the issued and outstanding equity of DP Lion Equity Holdco LLC. This entity is not consolidated

within the Group’s financial statements as of December 31, 2023. Refer to Note 5 for additional information.

(d)Owned 55% by Diversified Energy Company PLC.

NOTE 3 - SIGNIFICANT ACCOUNTING POLICIES

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

The preparation of the Group Financial Statements in compliance with IFRS as issued by the IASB requires management to

make estimates and exercise judgment in applying the Group’s accounting policies. In preparing the Group Financial

Statements, the significant judgments made by management in applying the Group’s accounting policies and the key sources

of estimation uncertainty are disclosed in Note 4.

Business Combinations and Asset Acquisitions

The Group performs an assessment of each acquisition to determine whether the acquisition should be accounted for as an

asset acquisition or a business combination. For each transaction, the Group may elect to apply the concentration test to

determine if the fair value of assets acquired is substantially concentrated in a single asset (or a group of similar assets). If this

concentration test is met, the acquisition qualifies as an acquisition of a group of assets and liabilities, not of a business.

Accounting for business combinations under IFRS 3 is applied once it is determined that a business has been acquired. Under

IFRS 3, a business is defined as an integrated set of activities and assets conducted and managed for the purpose of providing

a return to investors. A business generally consists of inputs, processes applied to those inputs, and resulting outputs that are,

or will be, used to generate revenues.

When less than the entire interest of an entity is acquired, the choice of measurement of the non-controlling interest, either at

fair value or at the proportionate share of the acquiree’s identifiable net assets, is determined on a transaction by

transaction basis.

More information regarding the judgments and conclusions reached with respect to business combinations and asset

acquisitions is included in Notes 4 and 5.

Oaktree Capital Management, L.P. (“Oaktree”) Participation Agreement

In October 2020, the Group entered into a three-year definitive participation agreement with funds managed by Oaktree to

jointly identify and fund future proved developed producing acquisition opportunities (“PDP acquisitions”) that the Group

identified. The Oaktree Funding Commitment provided for up to $1,000,000 in aggregate over three years for mutually agreed

upon PDP acquisitions with transaction valuations typically greater than $250,000. The Group and Oaktree each funded 50%

of the net purchase price in exchange for proportionate working interests of 51.25% and 48.75% during Tranche I deals, or joint

acquisitions made during the first 18 months of the agreement, and 52.5% and 47.5% during Tranche II deals, or joint

acquisitions made during the second 18 months of the agreement, respectively. The Group's greater share reflected the

upfront promote it received from Oaktree which was intended to compensate the Group for the increase in general and

administrative expenses needed to operate an entity that increases with acquired growth.

Additionally, upon Oaktree achieving a 10% unlevered internal rate of return, Oaktree would convey a back-end promote to

the Group which would increase the Group’s working interest to 59.625% for both Tranche I and Tranche II deals. The Group

also maintains the right of first offer to acquire Oaktree’s interest if and when Oaktree decides to divest. The Group and

Oaktree each have the right to participate in a sale by the other party with a third-party upon comparable terms.

The Group accounts for the Oaktree Participation Agreement as a joint operation under IFRS 11, Joint Arrangements (“IFRS

11”). Accordingly, the Group includes its proportionate share of assets, liabilities, revenues and expenses within the

consolidated financial statements.

The Oaktree Participation Agreement ended in October 2023. While Oaktree continues to hold the working interests it

acquired, the agreement to participate in future acquisition opportunities has expired.

Inventory

Natural gas inventory is stated at the lower of cost and net realizable value, cost being determined on a weighted average cost

basis. Inventory also consists of material and supplies used in connection with the Group’s maintenance, storage and handling.

Inventory is stated at the lower of cost or net realizable value.

Cash and Cash Equivalents

Cash on the balance sheet comprises cash at banks. Balances held at banks, at times, exceed U.S. federally insured amounts. The

Group has not experienced any losses in such accounts and the Directors believe the Group is not exposed to any significant credit

risk on its cash. As of December 31, 2023 and 2022, the Group’s cash balance was $3,753 and $7,329, respectively.

Trade Receivables

Trade receivables are stated at the historical carrying amount, net of any provisions required. Trade receivables are due from

customers throughout the natural gas and oil industry. Although dispersed among several customers, collectability is

dependent on the financial condition of each individual customer as well as the general economic conditions of the industry.

The Directors review the financial condition of customers prior to extending credit and generally do not require collateral to

182	Diversified Energy Company plc Annual Report and Form 20-F2023

support the recoverability of the Group’s trade receivables. Any changes in the Group’s allowance for expected credit losses

during the year are recognized in the Consolidated Statement of Comprehensive Income. Trade receivables also include

certain receivables from third-party working interest owners as well as hedge settlement receivables. The Group consistently

assesses the collectability of these receivables. As of December 31, 2023 and 2022, the Group considered a portion of these

working interest receivables uncollectable and recorded an allowance for credit losses in the amount of $16,529 and $8,941,

respectively. Refer to Note 14 for additional information.

Impairment of Financial Assets

IFRS 9 requires the application of an expected credit loss model in considering the impairment of financial assets. The

expected credit loss model requires the Group to account for expected credit losses and changes in those expected credit

losses at each reporting date to reflect changes in credit risk since initial recognition of the financial assets. The credit event

does not have to occur before credit losses are recognized. IFRS 9 allows for a simplified approach for measuring the loss

allowance at an amount equal to lifetime expected credit losses for trade receivables.

The Group applies the simplified approach to the expected credit loss model to trade receivables arising from:

—Sales of natural gas, NGLs and oil;

—Sales of gathering and transportation of third-party natural gas; and

—The provision of other services.

Borrowings

Borrowings are recognized initially at fair value, net of any applicable transaction costs incurred. Borrowings are subsequently

carried at amortized cost. Any difference between the proceeds (net of transaction costs) and the redemption value is

recognized in the Consolidated Statement of Comprehensive Income over the period of the borrowings using the effective

interest method.

Interest on borrowings is accrued as applicable to each class of borrowing.

Derivative Financial Instruments

Derivatives are used as part of the Group’s overall strategy to mitigate risk associated with the unpredictability of cash flows

due to volatility in commodity prices. Further details of the Group’s exposure to these risks are detailed in Note 25. The Group

has entered into financial instruments which are considered derivative contracts, such as swaps and collars, which result in net

cash settlements each month and do not result in physical deliveries. The derivative contracts are initially recognized at fair

value at the date the contract is entered into and remeasured to fair value every balance sheet date. The resulting gain or loss

is recognized in the Consolidated Statement of Comprehensive Income in the year incurred in the gain (loss) on derivative

financial instruments line item.

Restricted Cash

Cash held on deposit for bonding purposes is classified as restricted cash and recorded within current and non-current assets.

The cash (1) is restricted in use by state governmental agencies to be utilized and drawn upon if the operator should abandon

any wells, or (2) is being held as collateral by the Group’s surety bond providers.

Additionally, the Group is required to maintain certain reserves for interest payments related to its asset-backed

securitizations discussed in Note 21. These reserves approximate six to seven months of interest as well as any associated fees.

The Group classifies restricted cash as current or non-current based on the classification of the associated asset or liability to

which the restriction relates. This reserve cash is managed and held by an indenture trustee who monitors the reserve month

to month ensuring the proper quantum is maintained. This trustee is independent, and the conditions of the deposit prevent

the Group from accessing it on demand such that it no longer meets the definition of cash and cash equivalents.

	December 31, 2023	December 31, 2022
Cash restricted by asset-backed securitizations	$35,870	$54,552
Other restricted cash	382	836
Total restricted cash	$36,252	$55,388
Classified as:
Current asset	$11,195	$7,891
Non-current asset	25,057	47,497
Total	$36,252	$55,388
Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	183
---	---	---	---	---

Natural Gas and Oil Properties

Natural gas and oil activities are accounted for using the principles of the successful efforts method of accounting as described below.

DEVELOPMENT AND ACQUISITION COSTS

Costs incurred to purchase, lease, or otherwise acquire a property are capitalized when incurred. Expenditures related to the

construction, installation or completion of infrastructure facilities, such as platforms, and the drilling of development wells,

including delineation wells, are capitalized within natural gas and oil properties. The initial cost of an asset comprises its

purchase price or construction cost, any costs directly attributable to bringing the asset into operation, and the initial estimate

of the asset retirement obligation.

DEPLETION

Proved natural gas, oil and NGL reserve volumes are used as the basis to calculate unit-of-production depletion rates.

Leasehold costs are depleted on the unit-of-production basis over the total proved reserves of the relevant area while

production and development wells are depleted over proved producing reserves.

Intangible Assets

SOFTWARE DEVELOPMENT

Development costs that are directly attributable to the design and testing of identifiable and unique software products

controlled by the Group are recognized as intangible assets where the following criteria are met:

—It is technically feasible to complete the software so that it will be available for use;

—The Directors intend to complete the software and use or sell it;

—There is an ability to use the software;

—It can be demonstrated how the software will generate probable future economic benefits;

—Adequate technical, financial and other resources to complete the development and to use the software are available; and

—The expenditure attributable to the software during its development can be reliably measured.

Directly attributable costs that are capitalized as part of the software include cost incurred by third parties, employee costs

and an appropriate portion of relevant overheads. Capitalized development costs are recorded as intangible assets and

amortized from the point at which the asset is ready for use. Costs associated with maintaining software programs are

recognized as an expense as incurred.

IMPAIRMENT OF INTANGIBLE ASSETS

Intangible assets are tested for impairment whenever events or changes in circumstances indicate that the carrying amount may not

be recoverable. An impairment loss is recognized for the amount by which the asset’s carrying amount exceeds its recoverable

amount. The recoverable amount is the higher of an asset’s fair value less costs of disposal and value in use. For the purposes of

assessing impairment, assets are grouped at the lowest levels for which there are separately identifiable cash inflows which are

largely independent of the cash inflows from other assets or groups of assets (cash-generating units). Intangible assets that suffer an

impairment are reviewed for possible reversal of the impairment at the end of each reporting period.

AMORTIZATION

The Group amortizes intangible assets with a limited useful life, using the straight-line method over the following periods:

	Range in Years
Software	3 - 5
Other acquired intangibles(a)	3

(a)Represents intangible assets acquired in business combinations and asset acquisitions.

Property, Plant and Equipment

Property, plant and equipment are stated at cost less accumulated depreciation and impairment losses, if any. The cost of property,

plant and equipment initially recognized includes its purchase price and any cost that is directly attributable to bringing the asset to

the location and condition necessary for it to be capable of operating in the manner intended by the Directors.

Property, plant and equipment are generally depreciated on a straight-line basis over their estimated useful lives:

	Range in Years
Buildings and leasehold improvements	10 - 40
Equipment	5 - 10
Motor vehicles	5
Midstream assets	10 - 15
Other property and equipment	5 - 10
184	Diversified Energy Company plc Annual Report and Form 20-F2023
---	---

Property, plant and equipment held under leases are depreciated over the shorter of the lease term or estimated useful life.

Impairment of Non-Financial Assets

At each reporting date, the Directors assess whether indications exist that an asset may be impaired. If indications exist, or

when annual impairment testing for an asset is required, the Directors estimate the asset’s recoverable amount. An asset’s

recoverable amount is the higher of an asset’s, or cash generating unit’s, fair value less costs to sell and its value-in-use, and is

determined for an individual asset, unless the asset does not generate cash inflows that are largely independent of those from

other assets or groups of assets. Where the carrying amount of an asset or cash-generating unit exceeds its recoverable

amount, the Directors consider the asset impaired and write the asset down to its recoverable amount. In assessing value-in-

use, the Directors discount the estimated future cash flows to their present value using a discount rate that reflects current

market assessments of the time value of money and the risks specific to the asset. In determining fair value less costs to sell,

the Directors consider recent market transactions, if available. If no such transactions can be identified, the Directors will utilize

an appropriate valuation model.

Non-Controlling Interests

Non-controlling interests represent the equity in subsidiaries that is not attributable to the Group’s shareholders. The

acquisition of a non-controlling interest in a subsidiary and the sale of an interest while retaining control are accounted for as

transactions within equity and are reported within non-controlling interests in the consolidated financial statements.

During the years ended December 31, 2023, 2022 and 2021, the Group recorded $1,683, $4,812 and $303, respectively, of net

income attributable to non-controlling interests. As of December 31, 2023 and 2022, the Group had a non-controlling interests

balance of $12,604 and $14,964, respectively. During the years ended December 31, 2023, 2022 and 2021, the Group paid

$4,043, $6,389 and $0, respectively, in distributions to non-controlling interest owners.

Refer to Note 5 for information regarding the Group’s non-controlling interests in the Chesapeake Granite Wash Trust (“the

GWT”), acquired in connection with the Tapstone Acquisition in December 2021.

Leases

The Group recognizes a right-of-use asset and a lease liability at the commencement date of contracts (or separate

components of a contract) which convey to the Group the right to control the use of an identified asset for a period of time in

exchange for consideration, when such contracts meet the definition of a lease as determined by IFRS 16, Leases (“IFRS 16”).

The determination of whether an arrangement is, or contains, a lease is based on the substance of the arrangement at

inception date.

The Group initially measures the lease liability at the present value of the future lease payments. The lease payments are

discounted using the interest rate implicit in the lease. When this rate can not be readily determined, the Group uses its

incremental borrowing rate. After the commencement date, the lease liability is reduced for payments made by the lessee and

increased for interest on the lease liability.

Right-of-use assets are initially measured at cost, which comprises:

—The amount of the initial measurement of the lease liability;

—Any lease payments made at or before the commencement date, less any lease incentives received, any initial direct costs

incurred by the lessee; and

—An estimate of costs to be incurred by the lessee in dismantling and removing the underlying asset, restoring the site on

which it is located or restoring the underlying asset to the condition required by the terms and conditions of the lease

unless those costs are incurred to produce inventories.

Subsequent to the measurement date, the right-of-use asset is depreciated on a straight line basis for a period of time that

reflects the life of the underlying asset, and also adjusted for the remeasurement of any lease liability.

Asset Retirement Obligations

Where a liability for the retirement of a well, removal of production equipment and site restoration at the end of the

production life of a well exists, the Group recognizes a liability for asset retirement. The amount recognized is the present

value of estimated future net expenditures determined in accordance with our anticipated retirement plans as well as with

local conditions and requirements. The unwinding of the discount on the decommissioning liability is included as accretion of

the decommissioning provision. The cost of the relevant property, plant and equipment asset is increased with an amount

equivalent to the liability and depreciated on a unit of production basis. The Group recognizes changes in estimates

prospectively, with corresponding adjustments to the liability and the associated non-current asset.

As of December 31, 2023 and 2022, the Group had no midstream asset retirement obligations.

Taxation

DEFERRED TAXATION

Deferred tax assets and liabilities arise from temporary differences between the tax bases of assets and liabilities and their

carrying amounts in the Group Financial Statements. Deferred tax is determined using tax rates (and laws) that have been

enacted or substantially enacted by the balance sheet date and are expected to apply when the related deferred tax asset is

realized or the deferred liability is settled.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	185

Deferred tax assets are recognized to the extent that it is probable that the future taxable profit will be available against which

the temporary differences can be utilized.

CURRENT TAXATION

Current income tax assets and liabilities for the years ended December 31, 2023 and 2022 were measured at the amount to be

recovered from, or paid to, the taxation authorities. The tax rates and tax laws used to compute the amount are those that are

enacted or substantively enacted at the reporting date in the jurisdictions where the Group operates and generates

taxable income.

UNCERTAIN TAX POSITIONS

Management periodically evaluates positions taken in tax returns with respect to situations in which applicable tax regulation

is subject to interpretation and considers whether it is probable that a taxation authority will accept an uncertain tax

treatment. The Group measures its tax balances based on either the most likely amount, or the expected value, depending on

which method provides a better prediction of the resolution of the uncertainty.

Revenue Recognition

NATURAL GAS, NGLs AND OIL

Commodity revenue is derived from sales of natural gas, NGLs and oil products and is recognized when the customer obtains

control of the commodity. This transfer generally occurs when the product is physically transferred into a vessel, pipe, sales

meter or other delivery mechanism. This also represents the point at which the Group carries out its single performance

obligation to its customer under contracts for the sale of natural gas, NGLs and oil for the purposes of IFRS 15, Revenue from

Contracts with Customers (“IFRS 15”).

Commodity revenue in which the Group has an interest with other producers is recognized proportionately based on the

Group’s working interest and the terms of the relevant production sharing contracts. Royalty payments or counterparty

distributions, representing the portion of revenue that is due to minority working interests, is included as a liability, described

in Note 23.

Commodity revenue is recorded based on the volumes accepted each day by customers at the delivery point and is measured

using the respective market price index for the applicable commodity plus or minus the applicable basis differential based on

the quality of the product.

THIRD-PARTY GATHERING REVENUE

Revenue from gathering and transportation of third-party natural gas is recognized when the customer transfers its natural gas

to the entry point in the Group’s midstream network and becomes entitled to withdraw an equivalent volume of natural gas

from the exit point in the Group’s midstream network under contracts for the gathering and transportation of natural gas. This

transfer generally occurs when product is physically transferred into the Group’s vessel, pipe, or sales meter. The customer’s

entitlement to withdraw an equivalent volume of natural gas is broadly coterminous with the transfer of natural gas into the

Group’s midstream network. Customers are invoiced and revenue is recognized each month based on the volume of natural

gas transported at a contractually agreed upon price per unit.

THIRD-PARTY PLUGGING REVENUE

Revenue from third-party asset retirement services is recognized as earned in the month work is performed and consistent

with the Group’s contractual obligations. The Group’s contractual obligations in this respect are considered to be its

performance obligations for the purposes of IFRS 15.

OTHER REVENUE

Revenue from the operation of third-party wells is recognized as earned in the month work is performed and consistent with

the Group’s contractual obligations. The Group’s contractual obligations in this respect are considered to be its performance

obligations for the purposes of IFRS 15.

Revenue from the sale of water disposal services to third-parties into the Group’s disposal wells is recognized as earned in the

month the water was physically disposed at a contractually agreed upon price per unit. Disposal of the water is considered to

be the Group’s performance obligation under these contracts.

Revenue is stated after deducting sales taxes, excise duties and similar levies.

Share-Based Payments

The Group accounts for share-based payments under IFRS 2, Share-Based Payment (“IFRS 2”). All of the Group’s share-based

awards are equity settled. The fair value of the awards are determined at the date of grant. As of December 31, 2023, 2022 and

2021, the Group had three types of share-based payment awards: RSUs, PSUs and Options. The fair value of the Group’s RSUs

is measured using the stock price at the grant date. The fair value of the Group’s PSUs is measured using a Monte Carlo

simulation model. The inputs to the Monte Carlo simulation model included:

—The share price at the date of grant;

—Expected volatility;

—Expected dividends;

—Risk free rate of interest; and

186	Diversified Energy Company plc Annual Report and Form 20-F2023

—Patterns of exercise of the plan participants.

The fair value of the Group’s Options was calculated using the Black-Scholes model as of the grant date. The inputs to the

Black-Scholes model included:

—The share price at the date of grant;

—Exercise price;

—Expected volatility; and

—Risk-free rate of interest.

The grant date fair value of share-based awards, adjusted for market-based performance conditions, are expensed uniformly

over the vesting period.

New or Amended Accounting Standards - Adopted

The following accounting standards, amendments and interpretations became effective in the current year:

—Disclosure of Accounting Policies: IAS 1 and IFRS Practice Statement 2

—Deferred Tax Related to Assets and Liabilities Arising from a Single Transaction: Amendments to IAS 12

The application of these standards and interpretations effective for the first time in the current year has had no significant

impact on the amounts reported in the Group Financial Statements.

New or Amended Accounting Standards - Not Yet Adopted

At the date of authorization of the Group Financial Statements, the following standards and interpretations, which have not

been applied in the Group Financial Statements, were in issue but not yet effective. It is expected that where applicable, these

standards and amendments will be adopted on each respective effective date. None of these standards are expected to have a

significant impact on the Group.

Amendments to IFRS	Effective Date
Classification of Liabilities as Current or Non-Current and<br><br>Non-Current Liabilities with Covenants	Annual periods beginning on or after January 1, 2024

NOTE 4 - SIGNIFICANT ACCOUNTING JUDGMENTS AND ESTIMATES

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

In application of the Group's accounting policies, described in Note 3, the Directors have made the following judgments and

estimates which may have a significant effect on the amounts recognized in the Group Financial Statements.

Significant Judgments

BUSINESS COMBINATIONS AND ASSET ACQUISITIONS

The Group follows the guidance in IFRS 3, Business Combinations (“IFRS 3”) for determining the appropriate accounting

treatment for acquisitions. IFRS 3 permits an initial fair value assessment to determine if substantially all of the fair value of the

assets acquired is concentrated in a single asset or group of similar assets, the “concentration test”. If the initial screening test

is not met, the asset is considered a business based on whether there are inputs and substantive processes in place. Based on

the results of this analysis and conclusion on an acquisition’s classification of a business combination or an asset acquisition,

the accounting treatment is derived.

If the acquisition is deemed to be a business, the acquisition method of accounting is applied. Identifiable assets acquired and

liabilities assumed at the acquisition date are recorded at fair value. When the fair value exceeds the consideration

transferred, a bargain purchase gain is recognized. Conversely, when the consideration transferred exceeds the fair value,

goodwill is recorded. If the transaction is deemed to be an asset purchase, the cost accumulation and allocation model is used

whereby the assets and liabilities are recorded based on the purchase price and allocated to the individual assets and

liabilities based on relative fair values. As a result, gain on bargain purchases are not recognized on asset acquisitions.

Additionally, in instances when the acquisition of a group of assets contains contingent consideration, the Group records

changes in the fair value of the contingent consideration through the basis of the asset acquired rather than through the

Consolidated Statement of Comprehensive Income. More information regarding conclusions reached with respect to this

judgment is included in Note 5.

The determination and allocation of fair values to the identifiable assets acquired and liabilities assumed are based on various

market participant assumptions and valuation methodologies requiring considerable judgment by management. The most

significant variables in these valuations are discount rates and other assumptions and estimates used to determine the cash

inflows and outflows. Management determines discount rates based on the risk inherent in the acquired assets, specific risks,

industry beta and capital structure of guideline companies. The valuation of an acquired business is based on available

information at the acquisition date and assumptions that are believed to be reasonable. However, a change in facts and

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	187

circumstances as of the acquisition date can result in subsequent adjustments during the measurement period, but no later

than one year from the acquisition date.

Significant Estimates

ESTIMATING THE FAIR VALUE OF ACQUIRED NATURAL GAS AND OIL PROPERTIES

The Group determines the fair value of its natural gas and oil properties acquired in business combinations using the income

approach based on expected discounted future cash flows from estimated reserve quantities, costs to produce and develop

reserves, and natural gas and oil forward prices. The future net cash flows are discounted using a weighted average cost of

capital as well as any additional risk factors. Proved reserves are estimated by reference to available geological and

engineering data and only include volumes for which access to market is assured with reasonable certainty. Estimates of

proved reserves are inherently imprecise, require the application of judgment and are subject to regular revision, either upward

or downward, based on new information such as from the drilling of additional wells, observation of long-term reservoir

performance under producing conditions and changes in economic factors, including product prices, contract terms or

development plans.

IMPAIRMENT OF NATURAL GAS AND OIL PROPERTIES

In preparing the Group Financial Statements the Directors consider that a key judgment is whether there is any evidence that

the natural gas and oil properties are impaired. When making this assessment, producing assets are reviewed for indicators of

impairment at the balance sheet date. Indicators of impairment for the Group’s producing assets can include significant

or prolonged:

—Decreases in commodity pricing or other negative changes in market conditions;

—Downward revisions of reserve estimates; or

—Increases in operating costs.

The Group reviews the carrying value of its natural gas and oil properties on a field basis annually or when an indicator of

impairment is identified. The impairment test compares the carrying value of natural gas and oil properties to their recoverable

amount based on the present value of estimated future net cash flows from the proved natural gas and oil reserves. The future

cash flows are calculated using estimated reserve quantities, costs to produce and develop reserves, and natural gas and oil

forward prices. The fair value of proved reserves is estimated by reference to available geological and engineering data and

only includes volumes for which access to market is assured with reasonable certainty. When the carrying value is in excess of

the fair value, the Group recognizes an impairment by writing down the value of its natural gas and oil properties to their fair

value. During the year ended December 31, 2023, the Group determined that the carrying amounts of certain proved

properties for two fields were not recoverable from future cash flows and recognized an impairment charge of $41,616.

The Group assessed the sensitivity of the impairment analysis and noted the primary assumptions include pricing and the

selected discount rate. The Group performed the sensitivity analysis below under different scenarios considering the results of

the Group’s impairment assessment by field under the following scenarios: 1) a high and low pricing environment, using

historically observed average annual high and low prices for natural gas and oil over the last 10 years; and 2) a high and low

selected discount rate, using rates that the Group has observed in completed acquisitions over the last three years. These

changes in assumptions could have the following impact on the Group’s impairment analysis as of December 31, 2023:

Impact from Pricing	Scenario 1(a)	Scenario 2(b)
Headroom/(impairment)	$(473,510)	$7,532,007

(a)Scenario 1 includes commodity base prices of $2.04 and $39.23 for natural gas and oil, respectively, representing the lowest annual average

over the last 10 years. Under this scenario, 4 fields are impaired for a total impairment charge of $473,510.

(b)Scenario 2 includes commodity base prices of $6.42 and $94.79 for natural gas and oil, respectively, representing the highest annual average

over the last 10 years. Under this scenario, no fields are impaired.

Impact from Discount Rate	Scenario 1(a)	Scenario 2(b)
Headroom/(impairment)	$1,253,634	$627,047

(a)Scenario 1 represents the Group’s reserves at a discount rate of 9.5%, which represents the lowest rate used by the Group in an acquisition

over the past 3 years. Under this scenario, 1 field is impaired for a total impairment charge of $7,265.

(b)Scenario 2 represents the Group’s reserves at a discount rate of 13.5%, which represents the highest rate used by the Group in an acquisition

over the past 3 years. Under this scenario, 2 fields are impaired for a total impairment charge of $134,459.

No such impairments were recorded during the years ended December 31, 2022 and 2021. Refer to Note 10 for additional

information regarding the Group’s impairment assessment.

Where there has been a charge for impairment in an earlier period, that charge will be reversed in a later period when there

has been a change in circumstances to the extent that the recoverable amount is higher than the net book value at the time.

In reversing impairment losses, the carrying amount of the asset will be increased to the lower of its original carrying value or

the carrying value that would have been determined (net of depletion) had no impairment loss been recognized in prior

188	Diversified Energy Company plc Annual Report and Form 20-F2023

years. No such recoveries were recorded during the years ended December 31, 2023, 2022, and 2021. Please refer to Note 10

for additional information.

When applicable, the Group recognizes impairment losses in the Consolidated Statement of Comprehensive Income in those

expense categories consistent with the function of the impaired asset.

RESERVE VOLUME ESTIMATES

Proved reserves are the estimated volumes of natural gas, oil and NGLs that can be economically produced with reasonable

certainty from known reservoirs under existing economic conditions and operating methods.

In estimating proved natural gas and oil reserves, we rely on interpretations and judgment of available geological, geophysical,

engineering and production data as well as the use of certain economic assumptions such as commodity pricing. Additional

assumptions include operating expenses, capital expenditures and taxes. Many of the factors, assumptions and variables

involved in estimating proved reserves are subject to change over time and therefore affect the estimates of natural gas, oil

and NGL reserve volumes.

TAXATION

The Group makes certain estimates in calculating deferred tax assets and liabilities, as well as income tax expense. These

estimates often involve judgment regarding differences in the timing and recognition of revenue and expenses for tax and

financial reporting purposes as well as the tax basis of our assets and liabilities at the balance sheet date before tax returns are

completed. Additionally, the Group must assess the likelihood that it will be able to recover or utilize its deferred tax assets

and record a valuation allowance against deferred tax assets when all or a portion of that asset is not expected to be realized.

In evaluating whether a valuation allowance should be applied, the Group considers evidence such as future taxable income,

among other factors. This determination involves numerous judgments and assumptions and includes estimating factors such

as commodity prices, production and other operating conditions. If any of those factors, assumptions or judgments change,

the deferred tax asset could change and, in particular, decrease in a period where the Group determines it is more likely than

not that the asset will not be realized. Alternatively, a valuation allowance may be reversed where it is determined it is more

likely than not that the asset will be realized.

ASSET RETIREMENT OBLIGATION COSTS

The ultimate asset retirement obligation costs are uncertain and cost estimates can vary in response to many factors including

changes to relevant legal requirements, the emergence of new restoration techniques or experience at other production sites.

The expected timing and amount of expenditures can also change, for example, in response to changes in reserves or changes

in laws and regulations or their interpretation. As a result, significant estimates and assumptions are made in determining the

provision for asset retirement. These assumptions include the cost to retire the wells, the Group’s retirement plan, an assumed

inflation rate and the discount rate. Changes in assumptions related to the Group’s asset retirement obligations could result in

a material change in the carrying value within the next financial year. See Note 19 for more information and sensitivity analysis.

NOTE 5 - ACQUISITIONS AND DIVESTITURES

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

The assets acquired in all acquisitions include the necessary permits, rights to production, royalties, assignments, contracts and

agreements that support the production from wells and operation of pipelines. The Group determines the accounting

treatment of acquisitions using IFRS 3.

As part of the Group’s corporate strategy, it actively seeks to acquire assets when they meet the Group’s acquisition criteria of

being long-life, low-decline assets that strategically complement the Group’s existing portfolio.

2023 Acquisitions

TANOS ENERGY HOLDINGS II LLC (“TANOS II”) ASSET ACQUISITION

On March 1, 2023 the Group acquired certain upstream assets and related infrastructure in the Central Region from Tanos II.

Given the concentration of assets, this transaction was considered an asset acquisition rather than a business combination.

When making this determination management performed an asset concentration test considering the fair value of the acquired

assets. The Group paid purchase consideration of $262,329, inclusive of transaction costs of $936 and customary purchase

price adjustments. The Group funded the purchase with proceeds from the February 2023 equity raise, cash on hand and

existing availability on the Credit Facility for which the borrowing base was upsized concurrent to the closing of the Tanos II

transaction. Refer to Notes 16 and 21 for additional information regarding the Group’s share capital and borrowings. In the

period from its acquisition to December 31, 2023 the Tanos II assets increased the Group’s revenue by $45,589.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	189

The assets and liabilities assumed were as follows:

Consideration paid
Cash consideration	$262,329
Total consideration	$262,329
Net assets acquired
Natural gas and oil properties	$263,056
Asset retirement obligations, asset portion	3,250
Property, plant and equipment	234
Derivative financial instruments, net	7,449
Other receivables	1,729
Asset retirement obligations, liability portion	(3,250)
Other current liabilities	(10,139)
Net assets acquired	$262,329

2023 Divestitures

SALE OF EQUITY INTEREST IN DP LION EQUITY HOLDCO LLC

In November 2023, the Group formed DP Lion Equity Holdco LLC, a limited-purpose, bankruptcy-remote, wholly-owned

subsidiary, to issue Class A and Class B asset-backed securities (collectively “ABS VII”) which are secured by certain upstream

producing assets in Appalachia. The Class A and B asset backed securities were issued in aggregate principal amounts of

$142,000 and $20,000, respectively.

In December 2023, the Group divested 80% of the equity ownership in DP Lion Equity Holdco LLC to outside investors,

generating cash proceeds of $30,000. The Group evaluated the remaining 20% interest in DP Lion Equity Holdco LLC and

determined that the governance structure is such that the Group does not have the ability to exercise control, joint control, or

significant influence over the DP Lion Equity Holdco LLC entity. Accordingly, this entity is not consolidated within the Group’s

financial statements as of December 31, 2023. The total assets and liabilities divested are no longer consolidated within the

Group’s financial statements and were as follows:

Consideration received
Cash consideration	$(30,000)
Total consideration	$(30,000)
Net assets divested
Natural gas and oil properties	$(142,891)
Restricted cash	(7,345)
Derivative financial instruments, net	(20,328)
Other assets	(8,140)
Borrowings	154,966
Other liabilities	9,288
Net assets divested	$(14,450)
Cost basis of investment retained	2,890
Gain on sale of equity interest	$(18,440)

The consideration exceeded the fair value of the Group’s portion of the assets and liabilities divested resulting in a gain on sale

of the equity interest of $18,440. The Group’s remaining investment in the LLC is accounted for as an equity instrument at fair

value in accordance with IFRS 9, Financial Instruments (“IFRS 9”) and was $7,500 at December 31, 2023, which generated an

unrealized gain of $4,610.

On July 17, 2023, the Group sold undeveloped acreage in Oklahoma, within the Group’s Central Region, for net consideration

of approximately $16,060. The consideration received exceeded the fair value of the net assets divested resulting in a gain on

natural gas and oil properties and equipment of $13,619.

On June 27, 2023, the Group sold certain non-core, non-operated assets within its Central Region for gross consideration of

approximately $37,589. The divested assets were located in Texas and Oklahoma and consisted of non-operated wells and the

associated leasehold acreage that was acquired as part of the ConocoPhillips Asset Acquisition in September 2022. This sale

of non-operated and non-core assets aligns with the Group’s application of the Smarter Asset Management strategy and its

strategic focus on operated proved developed producing assets.

190	Diversified Energy Company plc Annual Report and Form 20-F2023

Additionally, during the year ended December 31, 2023, the Group divested certain other non-core undeveloped acreage

across its operating footprint for consideration of approximately $12,100. The consideration received exceeded the fair value of

the net assets divested resulting in a gain on natural gas and oil properties and equipment of $10,547.

2022 Acquisitions

CONOCOPHILLIPS ASSET ACQUISITION

On September 27, 2022 the Group acquired certain upstream assets and related facilities within the Central Region from

ConocoPhillips. Given the concentration of assets, this transaction was considered an asset acquisition rather than a business

combination. When making this determination management performed an asset concentration test considering the fair value

of the acquired assets. The Group paid purchase consideration of $209,766, including customary purchase price adjustments.

Transaction costs associated with the acquisition were negligible. The Group funded the purchase with available cash on hand

and a draw on the Credit Facility. In the period from its acquisition to December 31, 2022 the ConocoPhillips assets increased

the Group’s revenue by $25,217.

EAST TEXAS ASSET ACQUISITION

On April 25, 2022, the Group acquired a proportionate 52.5% working interest in certain upstream assets and related facilities

within the Central Region from a private seller in conjunction with Oaktree, via the previously disclosed participation

agreement between the two parties. Given the concentration of assets, this transaction was considered an asset acquisition

rather than a business combination. When making this determination, the Group performed an asset concentration test

considering the fair value of the acquired assets. The Group paid purchase consideration of $47,468, including customary

purchase price adjustments. Transaction costs associated with the acquisition were $1,550. The Group funded the purchase

with available cash on hand and a draw on the Credit Facility.

OTHER ACQUISITIONS

During the period ended December 31, 2022 the Group acquired three asset retirement companies for an aggregate

consideration of $13,949, inclusive of customary purchase price adjustments. The Group will also pay an additional $3,150 in

deferred consideration through November 2024. During the year ended December 31, 2023, the Group paid $2,100 of the

deferred consideration. When evaluating these transactions, the Group determined they did not have significant asset

concentrations and as a result it had acquired identifiable sets of inputs, processes and outputs and concluded the

transactions were business combinations.

On April 1, 2022 the Group acquired certain midstream assets, inclusive of a processing facility, in the Central Region that are

contiguous to its existing East Texas assets. The Group paid purchase consideration of $10,139, inclusive of customary

purchase price adjustments and transaction costs. When evaluating the transaction, the Group determined it did not have

significant asset concentration and as a result it had acquired an identifiable set of inputs, processes and outputs and

accordingly concluded the transaction was a business combination. The fair value of the net assets acquired was $10,742

generating a bargain purchase gain of $603.

On November 21, 2022 the Group acquired certain midstream assets in the Central Region that are contiguous to its existing

East Texas assets. The Group paid purchase consideration of $7,438, inclusive of customary purchase price adjustments and

transaction costs. Given the concentration of assets, this transaction was considered an asset acquisition rather than a

business combination.

Transaction costs associated with the other acquisitions noted above were insignificant and the Group funded the aggregate

cash consideration with existing cash on hand.

2021 Acquisitions

TAPSTONE ENERGY HOLDINGS LLC (“TAPSTONE”) BUSINESS COMBINATION

On December 7, 2021, the Group acquired a proportionate 51.25% working interest in certain upstream assets, field

infrastructure, equipment, and facilities within the Central Region from Tapstone in conjunction with Oaktree, via the

previously disclosed participation agreement between the two parties. The acquisition also included six wells which were

under development at the time of close which have now been completed by the Group. The Group serves as the sole operator

of the assets. When evaluating the transaction, the Group determined it did not have significant asset concentration and as a

result it had acquired an identifiable set of inputs, processes and outputs and concluded the transaction was a business

combination that resulted in a bargain purchase gain. The Group paid purchase consideration of $177,496, inclusive customary

purchase price adjustments. During 2022, the Group recorded $3,853 in measurement period adjustments as purchase

accounting was finalized. These adjustments were recorded as an increase in the bargain purchase gain associated with the

transaction. Transaction costs associated with the acquisition were $4,039 and were expensed. The Group funded the

purchase with proceeds from the Credit Facility.

In connection with the acquisition the Group also acquired the beneficial ownership in the Chesapeake Granite Wash Trust

(“the GWT”). The Group consolidated the GWT as it had determined that it controls the GWT because it (1) possesses power

over the GWT, (2) has exposure to variable returns from its involvement with the GWT, and (3) has the ability to use its power

over the GWT to affect its returns. The elements of control are achieved through the Group operating a majority of the natural

gas and oil properties that are subject to the conveyed royalty interests, marketing of the associated production, and through

its ownership of 50.8% of the outstanding common units of the GWT. The common units of the GWT owned by third parties

have been reflected as a non-controlling interest in the consolidated financial statements. Common units outstanding as of

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	191

December 7, 2021 were 46,750 with the Group’s beneficial interests in the GWT representing 50.8%. The GWT is publicly

traded and the GWT’s market capitalization was utilized when determining the value of the non-controlling interests.

The GWT’s non-controlling interest is heavily concentrated in the acquired Tapstone natural gas and oil properties and as a

result the Group consolidated $16,087 into its natural gas and oil properties associated with this non-controlling interest as of

December 31, 2021. The remaining amounts in the Group’s Consolidated Statement of Financial Position associated with non-

controlling interest were immaterial and working capital in nature.

TANOS ENERGY HOLDINGS III, LLC (“TANOS”) BUSINESS COMBINATION

On August 18, 2021, the Group acquired a 51.25% working interest in certain upstream assets, field infrastructure, equipment

and facilities within the Central Region from Tanos, in conjunction with Oaktree, via the previously disclosed participation

agreement between the two parties. When evaluating the transaction, the Group determined it did not have significant asset

concentration and as a result it had acquired an identifiable set of inputs, processes and outputs and concluded the

transaction was a business combination. The Group paid purchase consideration of $116,061, including customary purchase

price adjustments. Transaction costs associated with the acquisition were $2,384 and were expensed. DEC funded the

purchase with proceeds from a drawdown on the Credit Facility. During 2022 purchase accounting was finalized and no

measurement period adjustments were recorded.

As part of the acquisition, the Group obtained the option to novate or extinguish the Tanos hedge book. In conjunction with

the closing settlement, the Group elected to extinguish their share of the Tanos hedge book. The cost to terminate was

$52,666. This payment relieved the termination liability established in the Group’s Consolidated Statement of Financial Position

in purchase accounting and has been presented as an investing activity in the Consolidated Statement of Cash Flows given its

connection to the Tanos acquisition. New contracts were subsequently entered into for more favorable pricing in order to

secure the cash flows associated with these producing assets.

BLACKBEARD OPERATING LLC (“BLACKBEARD”) ASSET ACQUISITION

On July 5, 2021, the Group acquired certain upstream assets and related gathering infrastructure in the Central Region from

Blackbeard. Given the concentration of assets this transaction was considered an asset acquisition rather than a business

combination. When making this determination management performed an asset concentration test considering the fair value

of the acquired assets. The Group paid purchase consideration of $170,523, including customary purchase price adjustments

and transaction costs. Transaction costs associated with the acquisition were $3,644 and were capitalized to natural gas and

oil properties. The Group funded the purchase with proceeds from the May 2021 equity placement and a draw on the Credit

Facility, discussed in Notes 16 and 21, respectively. During 2022 purchase accounting was finalized and no measurement period

adjustments were recorded.

INDIGO ASSET ACQUISITION

On May 19, 2021, the Group acquired certain upstream assets and related gathering infrastructure in the Central Region from

Indigo. Given the concentration of assets this transaction was considered an acquisition of assets rather than a

business combination. When making this determination management performed an asset concentration test considering the

fair value of the acquired assets. The Group paid purchase consideration of $117,352, including customary purchase price

adjustments and transaction costs. Transaction costs associated with the acquisition were $473 and were capitalized to natural

gas and oil properties. The Group funded the purchase with proceeds from the May 2021 equity placement and a draw on the

Credit Facility, discussed in Notes 16 and 21, respectively. During 2022 purchase accounting was finalized and no measurement

period adjustments were recorded.

2021 Divestitures

INDIGO MINERALS LLC (“INDIGO”) DIVESTITURE

On July 9, 2021, the Group divested to Oaktree a non-operating 48.75% proportionate working interest in the Indigo assets

that were previously acquired (as disclosed above) by the Group on May 19, 2021. The initial consideration received was

$52,314, or 50% of the Group’s net purchase price on the Indigo assets which is consistent with the terms of the previously

disclosed participation agreement between the Group and Oaktree. The Group used the proceeds to reduce outstanding

balances on the Credit Facility.

In connection with the divestiture, the Group entered into a swap contract with Oaktree where the Group received a market

price and paid a fixed weighted average swap price of $2.86 per Mcfe. When considering the fair value of the swap

arrangement as well as the value of the upfront promote received from Oaktree at the date of close the Group realized a loss

of $1,461 on the divestiture.

OTHER DIVESTITURES

On December 23, 2021, the Group divested certain predominantly undeveloped Haynesville Shale acreage in Texas, acquired

as part of the Tanos acquisition. The total consideration received was $66,168 with DEC’s 51.25% interest through joint

ownership with Oaktree generating net proceeds of $33,911 to DEC inclusive of customary purchase price adjustments.

PRO FORMA INFORMATION (UNAUDITED)

The following table summarizes the unaudited pro forma condensed financial information of the Group as if the Indigo,

Blackbeard, Tanos and Tapstone acquisitions each had occurred on January 1, 2021, the East Texas Assets and ConocoPhillips

acquisition each had occurred on January 1, 2022, and the Tanos II acquisition had occurred on January 1, 2023.

192	Diversified Energy Company plc Annual Report and Form 20-F2023
	Year Ended
---	---	---	---
	December 31, 2023	December 31, 2022	December 31, 2021
Revenues	$883,347	$2,010,927	$1,249,983
Net income (loss)	804,649	(594,097)	(279,121)

The unaudited pro forma information is not necessarily indicative of the operating results that would have occurred had the

the Indigo, Blackbeard, Tanos and Tapstone acquisitions each been completed at January 1, 2021, the East Texas Assets and

ConocoPhillips acquisitions each been completed at January 1, 2022, and the Tanos II acquisition been completed at January 1,

2023, nor is it necessarily indicative of future operating results of the combined entities. The unaudited pro forma information

gives effect to the acquisitions and any related equity and debt issuances, along with the use of proceeds therefrom, as if they

had occurred on the respective dates discussed above and is a result of combining the statements of operations of the Group

with the pre-acquisition results of Indigo, Blackbeard, Tanos, Tapstone, East Texas Assets, ConocoPhillips, and Tanos II

including adjustment for revenues and direct expenses. The pro forma results exclude any cost savings anticipated as a result

of the acquisitions, and include adjustments to depreciation, depletion and amortization based on the purchase price allocated

to property, plant and equipment and the estimated useful lives as well as adjustments to interest expense.

Subsequent Event

On March 19, 2024 the Group announced it entered into a conditional agreement to acquire Oaktree’s proportionate interest in

the previously announced Indigo, Tanos III, East Texas and Tapstone acquisitions for an estimated gross purchase price of

$410,000 before customary purchase price adjustments. The transaction is expected to be funded through a combination of

existing and expanded liquidity, the assumption of Oaktree’s proportionate debt of approximately $120,000 associated with

the ABS VI amortizing note and approximately $90,000 in deferred cash payments to Oaktree. Additional liquidity for the

transaction may be generated from non-core asset sales and the potential issuance of a private placement preferred

instrument.

The Acquisition is classed as a class 1 transaction under the Listing Rules of the Financial Conduct Authority (“FCA”) and

accordingly it is conditional, amongst other things, on the approval of Diversified’s shareholders, by ordinary resolution, at a

general meeting of the Company.

NOTE 6 - REVENUE

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

The Group extracts and sells natural gas, NGLs and oil to various customers as well as operating a majority of these natural gas

and oil wells for customers and other working interest owners. In addition, the Group provides gathering and transportation

services as well as asset retirement and other services to third parties. All revenue was generated in the U.S.

The following table reconciles the Group's revenue for the periods presented:

	Year Ended
	December 31, 2023	December 31, 2022	December 31, 2021
Natural gas	$557,167	$1,544,658	$818,726
NGLs	141,321	188,733	115,747
Oil	103,911	139,620	38,634
Total commodity revenue	$802,399	$1,873,011	$973,107
Midstream	30,565	32,798	31,988
Other(a)	35,299	13,540	2,466
Total revenue	$868,263	$1,919,349	$1,007,561

(a)Includes $28,360 in third party plugging revenue and $6,939 in other revenue. Refer to Note 3 for additional information.

A significant portion of the Group’s trade receivables represent receivables related to either sales of natural gas, NGLs and oil

or operational services, all of which are uncollateralized, and are collected within 30 - 60 days.

During the year ended December 31, 2023, no customers individually comprised more than 10% of total revenues.

During the year ended December 31, 2022, no customers individually comprised more than 10% of total revenues.

During the year ended December 31, 2021, two customers individually comprised more than 10% of total revenues,

representing 22% of total revenues.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	193

NOTE 7 - EXPENSES BY NATURE

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

The following table provides detail of the Group's expenses for the periods presented:

	Year Ended
	December 31, 2023	December 31, 2022	December 31, 2021
LOE(a)	$213,078	$182,817	$119,594
Production taxes(b)	61,474	73,849	30,518
Midstream operating expenses(c)	69,792	71,154	60,481
Transportation expenses(d)	96,218	118,073	80,620
Total operating expenses	$440,562	$445,893	$291,213
Depreciation and amortization	56,453	51,877	44,841
Depletion	168,093	170,380	122,803
Total depreciation, depletion and amortization	$224,546	$222,257	$167,644
Employees, administrative costs and professional services(e)	78,659	77,172	56,812
Costs associated with acquisitions(f)	16,775	15,545	27,743
Other adjusting costs(g)	17,794	69,967	10,371
Non-cash equity compensation(h)	6,494	8,051	7,400
Total G&A	$119,722	$170,735	$102,326
Recurring allowance for credit losses(i)	8,478	—	(4,265)
Total expenses	$793,308	$838,885	$556,918
Aggregate remuneration (including Directors):
Wages and salaries	$124,834	$113,267	$83,790
Payroll taxes	10,163	9,516	7,137
Benefits	31,912	23,828	19,083
Total employees and benefits expense	$166,909	$146,611	$110,010

(a)LOE includes costs incurred to maintain producing properties. Such costs include direct and contract labor, repairs and maintenance, water

hauling, compression, automobile, insurance, and materials and supplies expenses.

(b)Production taxes include severance and property taxes. Severance taxes are generally paid on produced natural gas, NGLs and oil

production at fixed rates established by federal, state or local taxing authorities. Property taxes are generally based on the taxing

jurisdictions’ valuation of the Group’s natural gas and oil properties and midstream assets.

(c)Midstream operating expenses are daily costs incurred to operate the Group’s owned midstream assets inclusive of employee and

benefit expenses.

(d)Transportation expenses are daily costs incurred from third-party systems to gather, process and transport the Group’s natural gas, NGLs

and oil.

(e)Employees, administrative costs and professional services includes payroll and benefits for our administrative and corporate staff, costs of

maintaining administrative and corporate offices, costs of managing our production operations, franchise taxes, public company costs, fees

for audit and other professional services and legal compliance.

(f)The Group generally incurs costs related to the integration of acquisitions, which will vary for each acquisition. For acquisitions considered to

be a business combination, these costs include transaction costs directly associated with a successful acquisition transaction. These costs

also include costs associated with transition service arrangements where the Group pays the seller of the acquired entity a fee to handle

G&A functions until the Group has fully integrated the assets onto its systems. In addition, these costs include costs related to integrating IT

systems and consulting as well as internal workforce costs directly related to integrating acquisitions into the Group’s system.

(g)Other adjusting costs for the year ended December 31, 2023 were primarily associated with legal and professional fees related to the U.S.

listing, legal fees for certain litigation, and expenses associated with unused firm transportation agreements. Other adjusting costs for the

year ended December 31, 2022 primarily consisted of $28,345 in contract terminations which will allow the Group to obtain more favorable

pricing in the future and $31,099 in costs associated with deal breakage and/or sourcing costs for acquisitions. Other adjusting costs for the

year ended December 31, 2021 were primarily associated with one-time projects and contemplated transactions. Also included in other

adjusting costs were expenses associated with unused firm transportation agreements.

(h)Non-cash equity compensation reflects the expense recognition related to share-based compensation provided to certain key members of

the management team. Refer to Note 17 for additional information regarding non-cash share-based compensation.

(i)Allowance for credit losses consists of the recognition and reversal of credit losses. Refer to Note 14 for additional information regarding

credit losses.

194	Diversified Energy Company plc Annual Report and Form 20-F2023

The number of employees was as follows for the years presented (employee count not shown in thousands):

	Year Ended
	December 31, 2023	December 31, 2022	December 31, 2021
Number of production support employees, including<br><br>Directors	389	362	283
Number of production employees	1,214	1,220	1,143
Workforce	1,603	1,582	1,426

The Directors consider that the Group’s key management personnel comprise the Executive Directors. Bradley G. Gray is

included in the Executive Director remuneration below. Mr. Gray was a Director until September 15, 2023, but is no longer a

Director as of the date of this Annual Report & Form 20-F. The fixed pay figures included in the table represent Mr. Gray’s

prorated compensation for the year ended December 31, 2023. The Directors’ remuneration was as follows for the periods

presented:

	Year Ended
	December 31, 2023	December 31, 2022	December 31, 2021
Executive Directors
Salary	$1,073	$1,157	$1,119
Taxable benefits(a)	20	24	22
Benefit plan(b)	46	73	71
Bonus(c)	1,130	1,631	1,427
Long-term incentives(c)	2,322	3,193	3,018
Total Executive Directors' remuneration	$4,591	$6,078	$5,657
Non-Executive Directors
Fees	$994	$911	$683
Total Non-Executive Directors' remuneration	$994	$911	$683
Total remuneration	$5,585	$6,989	$6,340

(a)Taxable benefits were comprised of life insurance premiums and automobile reimbursements.

(b)Reflects matching contributions under the Group’s 401(k) plan.

(c)Further details of the bonus outcome for 2023 and long-term incentives can be found in the Remuneration Committee’s Report within this

Annual Report & Form 20-F.

Details of the highest paid Director’s aggregate emoluments and amounts receivable under long-term incentive schemes are

disclosed in the Remuneration Committee’s Report within this Annual Report & Form 20-F.

Auditors’ remuneration for the Group was as follows for the periods presented:

	Year Ended
	December 31, 2023	December 31, 2022	December 31, 2021
Auditors' remuneration
Fees payable to the Group’s external auditors and their<br><br>associates for the audit of the consolidated financial<br><br>statements(a)	$2,140	$1,790	$1,694
Fees payable for the audit of the financial statements of the<br><br>Company's subsidiaries(b)	150	160	—
Audit-related assurance services(c)	1,078	874	1,628
Other assurance services	13	—	—
Total auditors' remuneration	$3,381	$2,824	$3,322

(a)2023 fees include $249 in relation to additional fees agreed and billed in post signing the 2022 consolidated accounts.

(b)2022 fees have been revised to reflect additional scope change for the audit of the subsidiary accounts.

(c)Fees associated with the Group’s interim review and capital market activity which is outside the scope of the audit of the consolidated

financial statements. 2022 fees have been revised to reflect additional work performed for the interim review.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	195

NOTE 8 - TAXATION

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

The Group files a consolidated U.S. federal tax return, multiple state tax returns, and a separate UK tax return for the Parent

entity. The consolidated taxable income includes an allocable portion of income from the Group’s co-investments with Oaktree

and its investment in the Chesapeake Granite Wash Trust. Income taxes are provided for the tax effects of transactions

reported in the Group Financial Statements and consist of taxes currently due plus deferred taxes related to differences

between the basis of assets and liabilities for financial and income tax reporting.

For the taxable years ended December 31, 2023, 2022, and 2021, the Group had a tax expense of $240,643, benefit of

$178,904 and benefit of $225,694, respectively. The effective tax rate used for the year ended December 31, 2023 was 24.1%,

compared to 22.4% for the year ended December 31, 2022 and 41.0% for the year ended December 31, 2021.

The December 31, 2023 effective tax rate was primarily impacted by changes in state taxes as a result of acquisitions and

recurring permanent differences. The December 31, 2022 effective tax rate was primarily impacted by changes in state taxes as

a result of acquisitions. The December 31, 2021 effective tax rate was primarily impacted by the Group’s recognition of the U.S.

marginal well tax credit available to qualified producers in 2021, who operate lower-volume wells during a low commodity

pricing environment. The federal government provides these credits to encourage companies to continue operating lower-

volume wells during periods of low prices to maintain the underlying jobs they create and the state and local tax revenues they

generate for communities to support schools, social programs, law enforcement and other similar public services. The U.S.

marginal well tax credit is prescribed by Internal Revenue Code Section 45I and is available for certain natural gas production

from qualifying wells. The federal tax credit is intended to provide a benefit for wells producing less than 90 Mcfe per day

when market prices for natural gas for the previous tax year are relatively low. The Group benefited from this credit given its

portfolio of long-life, low-decline conventional wells. The tax credit was not available for tax year 2023 and 2022 due to

improved commodity prices during 2022 and 2021.

The provision for income taxes in the Consolidated Statement of Comprehensive Income is summarized below:

	Year Ended
	December 31, 2023	December 31, 2022	December 31, 2021
Current income tax (benefit) expense
Federal (benefit) expense	$7,289	$(513)	$25,738
State (benefit) expense	5,902	2,841	11,958
Foreign - UK (benefit) expense	—	107	(52)
Total current income tax (benefit) expense	$13,191	$2,435	$37,644
Deferred income tax (benefit) expense
Federal (benefit) expense	$202,133	$(169,531)	$(233,679)
State (benefit) expense	25,460	(11,863)	(29,597)
Foreign - UK (benefit) expense	(141)	55	(62)
Total deferred income tax (benefit) expense	$227,452	$(181,339)	$(263,338)
Total income tax (benefit) expense	$240,643	$(178,904)	$(225,694)

The effective tax rates and differences between the statutory U.S. federal income tax rate and the effective tax rates are

summarized as follows:

	Year Ended
	December 31, 2023	December 31, 2022	December 31, 2021
Income (loss) before taxation	$1,000,344	$(799,502)	$(550,900)
Income tax benefit (expenses)	(240,643)	178,904	225,694
Effective tax rate	24.1%	22.4%	41.0%
196	Diversified Energy Company plc Annual Report and Form 20-F2023
---	---
	Year Ended
---	---	---	---
	December 31, 2023	December 31, 2022	December 31, 2021
Expected tax at statutory U.S. federal income tax rate	21.0%	21.0%	21.0%
State income taxes, net of federal tax benefit	3.1%	1.2%	4.4%
Federal credits	—%	—%	15.4%
Other, net	—%	0.2%	0.2%
Effective tax rate	24.1%	22.4%	41.0%

The Group had a net deferred tax asset of $131,206 at December 31, 2023 compared to a net deferred tax asset of $358,666 at

December 31, 2022. The change was primarily due to a poor commodity price environment generating unrealized gains for

unsettled derivatives not recognized for tax purposes. The Group had a net deferred tax asset of $358,666 at December 31,

2022 compared to a net deferred tax asset of $176,954 at December 31, 2021. The change was primarily due to an improved

commodity price environment generating unrealized losses for unsettled derivatives not recognized for tax purposes. The

presentation in the balance sheet takes into consideration the offsetting of deferred tax assets and deferred tax liabilities

within the same tax jurisdiction, where permitted. The overall deferred tax position in a particular tax jurisdiction determines if

a deferred tax balance related to that jurisdiction is presented within deferred tax assets or deferred tax liabilities.

The following table presents the components of the net deferred tax asset included in non-current assets as of the periods

presented:

	December 31, 2023	December 31, 2022
Deferred tax asset
Asset retirement obligations	$103,998	$92,393
Derivative financial instruments	153,057	378,918
Allowance for doubtful accounts	4,235	2,378
Net operating loss carryover	686	3,865
Federal tax credits carryover	163,158	184,975
163(j) interest expense limitation	24,324	15,573
Other	8,695	18,934
Total deferred tax asset	$458,153	$697,036
Deferred tax liability
Amortization and depreciation	$(252,587)	$(255,440)
Investment in partnerships	(74,360)	(82,930)
Total deferred tax liability	$(326,947)	$(338,370)
Net deferred tax asset (liability)	$131,206	$358,666
Balance sheet presentation
Deferred tax asset	$144,860	$371,156
Deferred tax liability	(13,654)	(12,490)
Net deferred tax asset (liability)	$131,206	$358,666

In assessing the realizability of deferred tax assets, the Group considers whether it is probable that some or all of the deferred

tax assets will not be realized. The ultimate realization of deferred tax assets is dependent upon the generation of future

taxable income during the periods in which those temporary differences become deductible or before credits expire. The

Group considers the scheduled reversal of deferred tax liabilities, projected future taxable income and tax planning strategies

in making this assessment. The Group has determined, at this time, it will have sufficient future taxable income to recognize its

deferred tax assets.

The Group reported the effects of deferred tax expense as of and for the year ended December 31, 2023:

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	197
	Opening Balance	Consolidated<br><br>Statement of<br><br>Comprehensive<br><br>Income	Other(a)	Closing Balance
---	---	---	---	---
Asset retirement obligations	$92,393	$11,605	$—	$103,998
Allowance for doubtful accounts	2,378	1,857	—	4,235
Net operating loss carryover	3,865	(3,179)	—	686
Federal tax credits carryover	184,975	(21,817)	—	163,158
Property, plant, and equipment and natural<br><br>gas and oil properties	(255,440)	2,853	—	(252,587)
Derivative financial instruments	378,918	(225,861)	—	153,057
Investment in partnerships	(82,930)	8,570	—	(74,360)
163(j) interest expense limitation	15,573	8,751		24,324
Other	18,934	(10,231)	(8)	8,695
Total deferred tax asset (liability)	$358,666	$(227,452)	$(8)	$131,206

(a)Amounts primarily relate to deferred taxes acquired as part of acquisition purchase accounting.

The Group reported the effects of deferred tax expense as of and for the year ended December 31, 2022:

	Opening Balance	Consolidated<br><br>Statement of<br><br>Comprehensive<br><br>Income	Other(a)	Closing Balance
Asset retirement obligations	$114,182	$(21,789)	$—	$92,393
Allowance for doubtful accounts	1,734	644	—	2,378
Net operating loss carryover	562	3,360	(57)	3,865
Federal tax credits carryover	183,460	1,515	—	184,975
Property, plant, and equipment and natural<br><br>gas and oil properties	(266,987)	11,360	187	(255,440)
Derivative financial instruments	202,802	176,116	—	378,918
Investment in partnerships	(72,105)	(11,068)	243	(82,930)
163(j) interest expense limitation	—	15,573		15,573
Other	13,306	5,628	—	18,934
Total deferred tax asset (liability)	$176,954	$181,339	$373	$358,666

(a)Amounts primarily relate to deferred taxes acquired as part of acquisition purchase accounting.

The Group reported the effects of deferred tax expense as of and for the year ended December 31, 2021:

	Opening Balance	Consolidated<br><br>Statement of<br><br>Comprehensive<br><br>Income	Other(a)	Closing Balance
Asset retirement obligations	$90,949	$19,052	$4,181	$114,182
Allowance for doubtful accounts	2,968	(1,320)	86	1,734
Net operating loss carryover	474	(1,655)	1,743	562
Federal tax credits carryover	99,117	84,343	—	183,460
Property, plant, and equipment and natural<br><br>gas and oil properties	(244,874)	65,910	(88,023)	(266,987)
Derivative financial instruments	46,237	156,565	—	202,802
Investment in partnerships	—	(67,379)	(4,726)	(72,105)
Other	4,160	7,822	1,324	13,306
Total deferred tax asset (liability)	$(969)	$263,338	$(85,415)	$176,954

(a)Amounts primarily relate to deferred taxes acquired as part of acquisition purchase accounting.

198	Diversified Energy Company plc Annual Report and Form 20-F2023

The Group’s material deferred tax assets and liabilities all arise in the U.S.

For U.S. federal tax purposes, the Group is taxed as one consolidated entity. The Group’s co-investments with Oaktree and its

investment in the Chesapeake Granite Wash Trust are taxed as partnerships that pass through to the Group’s consolidated

return. The Group is subject to additional taxes in its domiciled jurisdiction of the UK. For the years ended December 31, 2023,

2022, and 2021, the Group incurred no tax impact, an expense of $107, and a benefit of $52 in the UK, respectively.

The Group has considered the impact of Pillar Two income taxes and does not expect this to impact current tax expense in the

current year.

The Group had no uncertain tax position liabilities as of December 31, 2023, 2022 or 2021.

As of December 31, 2023, the Group had U.S. federal net operating loss carryforwards (“NOLs”) of approximately $1,600, of

which $1,504 are subject to limitation. Additionally, the Group had U.S. state NOLs of approximately $4,025, which expire in

the years 2035 through 2038.

The Group had U.S. marginal well tax credit carryforwards of approximately $163,158 as of December 31, 2023 compared to

$184,975 as of December 31, 2022. The Group had U.S. marginal well tax credit carryforwards of approximately $184,975 as of

December 31, 2022 compared to $183,460 as of December 31, 2021. As discussed earlier, the federal tax credit is intended to

provide a benefit for wells producing less than 90 Mcfe per day when market prices for natural gas are relatively low. Due to

the improved commodity price environment in 2022, the Group did not generate federal tax credits for the year ended

December 31, 2023. The tax credits expire in the years 2038 through 2042.

The Group had no U.S. federal capital loss carryforwards as of December 31, 2023 compared to $21,401 as of December 31,

The Group had U.S. federal capital loss carryforwards of $21,401 as of December 31, 2022 compared to $9,904 as of

December 31, 2021. For the year ended December 31, 2023, no capital loss carryforwards expired. The Group utilized all of the

existing capital loss carryforward in the amount of $23,102 in 2023, therefore there is no capital loss carryforward going

into 2024.

The Group completed a Section 382 study through December 31, 2023 in accordance with the Internal Revenue Code of 1986,

as amended. If the Group experiences an ownership change, tax credit carryforwards can be utilized but are limited each year

and could expire before they are fully utilized. The study concluded that the Group has not experienced an ownership change

as defined by Section 382 since the last ownership change that occurred on January 31, 2018. The Directors expect its tax

credit carryforwards, limited by the January 31, 2018 ownership change, to be fully available for utilization by 2024.

NOTE 9 - EARNINGS (LOSS) PER SHARE

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

The calculation of basic earnings (loss) per share is based on net income (loss) and on the weighted average number of shares

outstanding during the period. The calculation of diluted earnings per share is based on net income (loss) and the weighted

average number of shares outstanding plus the weighted average number of shares that would be issued if dilutive options

and warrants were converted into shares on the last day of the reporting period. The weighted average number of shares

outstanding for the computation of both basic and diluted earnings (loss) per share excludes shares held as treasury shares in

the Employee Benefit Trust (“EBT”), which for accounting purposes are treated in the same manner as shares held in the

treasury reserve. Refer to Note 16 for additional information regarding the EBT.

Effective December 5, 2023, the Company executed a 20-for-1 consolidation of its outstanding shares. The Group’s weighted

average shares outstanding and earnings (loss) per share calculation have been retroactively adjusted for all reporting periods.

Basic and diluted earnings (loss) per share are calculated as follows for the periods presented:

		Year Ended
	Calculation	December 31, 2023	December 31, 2022	December 31, 2021
Net income (loss) attributable to Diversified<br><br>Energy Company PLC	A	$758,018	$(625,410)	$(325,509)
Weighted average shares outstanding - basic	B	47,165	42,204	39,677
Dilutive impact of potential shares		349	—	—
Weighted average shares outstanding - diluted	C	47,514	42,204	39,677
Earnings (loss) per share - basic	= A/B	$16.07	$(14.82)	$(8.20)
Earnings (loss) per share - diluted	= A/C	$15.95	$(14.82)	$(8.20)
Potentially dilutive shares(a)		54	767	325

(a)Outstanding share-based payment awards excluded from the diluted EPS calculation because their effect would have been anti-dilutive.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	199

NOTE 10 - NATURAL GAS AND OIL PROPERTIES

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

The following table summarizes the Group's natural gas and oil properties for the periods presented:


	December 31, 2023	December 31, 2022	December 31, 2021
Costs
Beginning balance	$3,062,463	$2,866,353	$1,968,557
Additions(a)	353,888	219,490	1,012,691
Disposals(b)	(209,612)	(23,380)	(114,895)
Ending balance	$3,206,739	$3,062,463	$2,866,353
Depletion and impairment
Beginning balance	$(506,655)	$(336,275)	$(213,472)
Depletion expense	(168,093)	(170,380)	(122,803)
Impairment	(41,616)	—	—
Ending balance	$(716,364)	$(506,655)	$(336,275)
Net book value	$2,490,375	$2,555,808	$2,530,078

(a)For the year ended December 31, 2023, the Group added $266,306 related to acquisitions and $42,650 resulting from normal revisions to

the Group’s asset retirement obligations. The remaining change is primarily attributable to recurring capital expenditures. For the year ended

December 31, 2022, the Company added $285,212 related to acquisitions, offset by $98,802 resulting from normal revisions to the

Company’s asset retirement obligations. The remaining additions are primarily attributable to capital expenditures associated with the

completion of five Tapstone wells that were under development as of December 31, 2021, and seven additional wells in which the Group

participated with a non-operating interest in Appalachia. The remaining change is primarily attributable to recurring capital expenditures.

For the year ended December 31, 2021, the Group added $907,383 related to acquisitions and $78,156 resulting from normal revisions to the

Group’s asset retirement obligations. The remaining change is primarily attributable to recurring capital expenditures and the revaluation of

the EQT contingent consideration. Refer to Notes 5 and 19 for additional information regarding acquisitions and asset retirement

obligations, respectively.

(b)For the year ended December 31, 2023, the Group divested $202,886 in natural gas and oil properties related to the sale of equity interest in

DP Lion Equity Holdco LLC, the divested assets previously acquired as part of the ConocoPhillips Asset Acquisition, and other proved

properties and undeveloped acreage divestitures. Disposals for the year ended December 31, 2022 were associated with divestitures of

natural gas and oil properties in the normal course of business, none of which were material. For the year ended December 31, 2021, the

Group divested $113,752 in natural gas and oil properties related to the Indigo and Tanos undeveloped acreage transactions. Refer to Note 5

for additional information regarding divestitures.

Impairment Assessment for Natural Gas and Oil Properties

For the period ended December 31, 2023, the Directors assessed the indicators of impairment, noting depressed commodity

prices represented an indicator of potential impairment. The estimated future cash flows expected in connection with each

field are compared to the carrying amount of the field to determine if the carrying amount is recoverable. Due to the

unavailability of relevant comparable market data, a discounted cash flow method is used to determine the fair value of proved

properties. Significant unobservable inputs (Level 3) utilized in the determination of discounted future net cash flows include

future commodity prices adjusted for differentials, forecasted production based on decline curve analysis, estimated future

operating costs, property ownership interests, and a 10.9% discount rate. For the year ended December 31, 2023, the Company

determined the carrying amounts of certain proved properties within two fields were not recoverable from future cash flows,

and therefore, were impaired. Such impairments totaled $41,616 for the year ended December 31, 2023.

For the years ended December 31, 2022 and December 31, 2021, estimated future cash flows were determined to be in excess

of cost basis, and therefore no impairments were recorded for the Group’s natural gas and oil properties.

200	Diversified Energy Company plc Annual Report and Form 20-F2023

NOTE 11 - PROPERTY, PLANT AND EQUIPMENT

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

The following tables summarize the Group’s property, plant and equipment for the periods presented:

	Year Ended December 31, 2023
	Buildings and<br><br>Leasehold<br><br>Improvements	Equipment	Motor<br><br>Vehicles	Midstream<br><br>Assets	Other<br><br>Property<br><br>and<br><br>Equipment	Total
Costs
Beginning balance	$47,682	$30,369	$66,389	$433,484	$23,743	$601,667
Additions(a)	1,134	3,964	11,715	21,644	4,039	42,496
Disposals	(561)	(2,097)	(6,929)	—	(1,489)	(11,076)
Ending balance(b)	$48,255	$32,236	$71,175	$455,128	$26,293	$633,087
Accumulated depreciation
Beginning balance	$(3,607)	$(7,627)	$(29,194)	$(95,826)	$(2,553)	$(138,807)
Period changes	(581)	(3,024)	(12,887)	(27,632)	(2,720)	(46,844)
Disposals	27	1,929	5,939	—	877	8,772
Ending balance	$(4,161)	$(8,722)	$(36,142)	$(123,458)	$(4,396)	$(176,879)
Net book value	$44,094	$23,514	$35,033	$331,670	$21,897	$456,208	Year Ended December 31, 2022
---	---	---	---	---	---	---
	Buildings and<br><br>Leasehold<br><br>Improvements	Equipment	Motor<br><br>Vehicles	Midstream<br><br>Assets	Other<br><br>Property<br><br>and<br><br>Equipment	Total
Costs
Beginning balance	$41,684	$9,492	$45,562	$398,663	$16,039	$511,440
Additions(a)	9,421	20,886	22,399	34,835	7,704	95,245
Disposals	(3,423)	(9)	(1,572)	(14)	—	(5,018)
Ending balance(b)	$47,682	$30,369	$66,389	$433,484	$23,743	$601,667
Accumulated depreciation
Beginning balance	$(2,078)	$(4,089)	$(20,186)	$(69,501)	$(1,606)	$(97,460)
Period changes	(1,819)	(3,547)	(10,270)	(26,330)	(947)	(42,913)
Disposals	290	9	1,262	5	—	1,566
Ending balance	$(3,607)	$(7,627)	$(29,194)	$(95,826)	$(2,553)	$(138,807)
Net book value	$44,075	$22,742	$37,195	$337,658	$21,190	$462,860
Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	201
---	---	---	---	---
	Year Ended December 31, 2021
---	---	---	---	---	---	---
	Buildings and<br><br>Leasehold<br><br>Improvements	Equipment	Motor<br><br>Vehicles	Midstream<br><br>Assets	Other<br><br>Property<br><br>and<br><br>Equipment	Total
Costs
Beginning balance	$28,190	$6,768	$35,129	$367,331	$5,600	$443,018
Additions(a)	13,494	2,737	12,700	31,485	10,439	70,855
Disposals	—	(13)	(2,267)	(153)	—	(2,433)
Ending balance(b)	$41,684	$9,492	$45,562	$398,663	$16,039	$511,440
Accumulated depreciation
Beginning balance	$(1,007)	$(2,860)	$(12,409)	$(43,597)	$(1,042)	$(60,915)
Period changes	(1,071)	(1,231)	(9,259)	(25,928)	(564)	(38,053)
Disposals	—	2	1,482	24	—	1,508
Ending balance	$(2,078)	$(4,089)	$(20,186)	$(69,501)	$(1,606)	$(97,460)
Net book value	$39,606	$5,403	$25,376	$329,162	$14,433	$413,980

(a)Of the $42,496 in 2023 additions, $234 was related to acquisitions and $13,279 was associated with right-of-use asset additions for new

leases. Of the $95,245 in 2022 additions, $26,815 was related to acquisitions and $11,295 was associated with right-of-use asset additions for

new leases. The remaining capital expenditures are a result of our recurring capital needs and enhanced sustainability efforts. Of the $70,855

in 2021 additions, $25,961 was related to acquisitions and $16,554 was associated with right-of-use asset additions for new and acquired

leases. Refer to Notes 5 and 20 for additional information regarding acquisitions and leases, respectively. Remaining additions are related to

routine capital projects on the Group’s compressor and gathering systems, vehicle and equipment additions.

(b)Buildings and Leasehold Improvements and Motor Vehicles are inclusive of right-of-use assets associated with the Group’s leases. Refer to

Note 20 for additional information regarding leases.

The Group continued to utilize certain fully depreciated assets during the years ended December 31, 2023, 2022 and 2021 with

an original cost basis of $6,546, $9,222 and $5,597, respectively.

NOTE 12 - INTANGIBLE ASSETS

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

Intangible assets consisted of the following for the periods presented:

	Year Ended December 31, 2023
	Software	Other Acquired<br><br>Intangibles	Total
Costs
Beginning balance	$39,306	$7,124	$46,430
Additions(a)	5,949	—	5,949
Disposals	(806)	(2,900)	(3,706)
Ending balance	$44,449	$4,224	$48,673
Accumulated amortization
Beginning balance	$(22,517)	$(2,815)	$(25,332)
Period changes	(6,789)	(907)	(7,696)
Disposals	806	2,900	3,706
Ending balance	$(28,500)	$(822)	$(29,322)
Net book value	$15,949	$3,402	$19,351
202	Diversified Energy Company plc Annual Report and Form 20-F2023
---	---
	Year Ended December 31, 2022
---	---	---	---
	Software	Other Acquired<br><br>Intangibles	Total
Costs
Beginning balance	$28,095	$2,900	$30,995
Additions(a)	11,211	4,224	15,435
Ending balance	$39,306	$7,124	$46,430
Accumulated amortization
Beginning balance	$(15,192)	$(1,669)	$(16,861)
Period changes	(7,325)	(1,146)	(8,471)
Ending balance	$(22,517)	$(2,815)	$(25,332)
Net book value	$16,789	$4,309	$21,098	Year Ended December 31, 2021
---	---	---	---
	Software	Other Acquired<br><br>Intangibles	Total
Costs
Beginning balance	$24,271	$2,900	$27,171
Additions(a)	3,824	—	3,824
Ending balance	$28,095	$2,900	$30,995
Accumulated amortization
Beginning balance	$(7,246)	$(712)	$(7,958)
Period changes	(7,946)	(957)	(8,903)
Ending balance	$(15,192)	$(1,669)	$(16,861)
Net book value	$12,903	$1,231	$14,134

(a)For the years ended December 31, 2023, 2022 and 2021 additions were related to software enhancements and other acquired intangibles.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	203

NOTE 13 - DERIVATIVE FINANCIAL INSTRUMENTS

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

The Group is exposed to volatility in market prices and basis differentials for natural gas, NGLs and oil, which impacts the

predictability of its cash flows related to the sale of those commodities. The Group can also have exposure to volatility in

interest rate markets, depending on the makeup of its debt structure, which impacts the predictability of its cash flows related

to interest payments on the Group’s variable rate debt obligations. These risks are managed by the Group’s use of certain

derivative financial instruments. As of December 31, 2023, the Group’s derivative financial instruments consisted of swaps,

collars, basis swaps, stand-alone put and call options, and swaptions. A description of these instruments is as follows:

Swaps:	If the Group sells a swap, it receives a fixed price for the contract and pays a floating market price to<br><br>the counterparty;
Collars:	Arrangements that contain a fixed floor price (purchased put option) and a fixed ceiling price (sold call<br><br>option) based on an index price which, in aggregate, have no net costs. At the contract settlement date,<br><br>(1) if the index price is higher than the ceiling price, the Group pays the counterparty the difference<br><br>between the index price and ceiling price, (2) if the index price is between the floor and ceiling prices, no<br><br>payments are due from either party, and (3) if the index price is below the floor price, the Group will<br><br>receive the difference between the floor price and the index price.<br><br>Certain collar arrangements may also include a sold put option with a strike price below the purchased put<br><br>option. Referred to as a three-way collar, the structure works similar to the above description, except that<br><br>when the index price settles below the sold put option, the Group pays the counterparty the difference<br><br>between the index price and sold put option, effectively enhancing realized pricing by the difference<br><br>between the price of the sold and purchased put option;
Basis swaps:	Arrangements that guarantee a price differential for commodities from a specified delivery point. If the<br><br>Group sells a basis swap, it receives a payment from the counterparty if the price differential is greater<br><br>than the stated terms of the contract and pays the counterparty if the price differential is less than the<br><br>stated terms of the contract;
Put options:	The Group purchases and sells put options in exchange for a premium. If the Group purchases a put<br><br>option, it receives from the counterparty the excess (if any) of the market price below the strike price of<br><br>the put option at the time of settlement, but if the market price is above the put’s strike price, no payment<br><br>is due from either party. If the Group sells a put option, the Group pays the counterparty the excess (if<br><br>any) of the market price below the strike price of the put option at the time of settlement, but if the<br><br>market price is above the put’s strike price, no payment is due from either party;
Call options:	The Group purchases and sells call options in exchange for a premium. If the Group purchases a call<br><br>option, it receives from the counterparty the excess (if any) of the market price over the strike price of the<br><br>call option at the time of settlement, but if the market price is below the call’s strike price, no payment is<br><br>due from either party. If the Group sells a call option, it pays the counterparty the excess (if any) of the<br><br>market price over the strike price of the call option at the time of settlement, but if the market price is<br><br>below the call’s strike price, no payment is due from either party; and
Swaptions:	If the Group sells a swaption, the counterparty will receive the option to enter into a swap contract at a<br><br>specified date and receives a fixed price for the contract and pays a floating market price to the<br><br>counterparty.

The Group may elect to enter into offsetting transactions for the above instruments for the purpose of cancelling or

terminating certain positions.

204	Diversified Energy Company plc Annual Report and Form 20-F2023

The following tables summarize the Group's calculated net fair value of derivative financial instruments as of the reporting date

as follows:

NATURAL GAS CONTRACTS		Weighted Average Price per Mcfe(a)
	Volume		Sold	Purchased	Sold	Basis	Fair Value at
	(Mmbtu)	Swaps	Puts	Puts	Calls	Differential	December 31, 2023
2024
Swaps	191,397	$3.30	$—	$—	$—	$—	$74,340
Collars	2,560	—	—	4.03	6.25	—	3,278
Stand-Alone Calls, net(b)	—	—	—	—	—	—	(36,415)
Basis Swaps	163,595	—	—	—	—	(0.73)	(1,306)
Total 2024 contracts	357,552						39,897
2025
Swaps	164,672	$3.21	$—	$—	$—	$—	$(76,697)
Stand-Alone Calls, net(b)	—	—	—	—	—	—	(33,060)
Basis Swaps	25,550	—	—	—	—	(0.21)	372
Total 2025 contracts	190,222						(109,385)
2026
Swaps	120,559	$3.18	$—	$—	$—	$—	$(95,779)
Stand-Alone Calls	10,950	—	—	—	3.75	—	(8,153)
Basis Swaps	10,950	—	—	—	—	(0.21)	(342)
Total 2026 contracts	142,459						(104,274)
2027
Swaps	101,303	$3.21	$—	$—	$—	$—	$(76,188)
Collars	1,414	—	—	4.28	7.17	—	601
Stand-Alone Calls	10,950	—	—	—	3.75	—	(8,784)
Purchased puts	4,906	—	—	2.25	—	—	498
Sold puts	4,906	—	1.93	—	—	—	(275)
2028
Swaps	71,324	$2.79	$—	$—	$—	$—	$(71,625)
Collars	5,382	—	—	4.28	6.90	—	2,616
Purchased puts	20,351	—	—	2.77	—	—	8,622
Sold puts	20,351	—	1.93	—	—	—	(4,711)
2029
Swaps	29,190	$2.11	$—	$—	$—	$—	$(40,451)
Collars	3,726	—	—	4.28	7.51	—	2,150
Purchased puts	30,066	—	—	2.92	—	—	10,782
Sold puts	30,066	—	1.93	—	—	—	(3,257)
2030
Swaps	5,450	$2.03	$—	$—	$—	$—	$(7,979)
Purchased puts	14,492	—	—	2.93	—	—	5,362
Sold puts	14,492	—	1.93	—	—	—	(1,735)
Swaptions
10/1/2024-9/30/2028(c)	14,610	$2.91	$—	$—	$—	$—	$(12,749)
1/1/2025-12/31/2029(d)	36,520	2.77	—	—	—	—	(36,684)
4/1/2026-3/31/2030(e)	82,171	2.57	—	—	—	—	(97,901)
4/1/2030-3/31/2032(f)	42,627	2.57	—	—	—	—	(47,143)
Total 2027-2032 contracts	544,297						$(378,851)
Total natural gas contracts	1,234,530						$(552,613)

(a)Rates have been converted from Btu to Mcfe using a Btu conversion factor of 1.07.

(b)Future cash settlements for deferred premiums.

(c)Option expires on September 6, 2024.

(d)Option expires on December 23, 2024.

(e)Option expires on March 23, 2026.

(f)Option expires on March 22, 2030.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	205
NGLs CONTRACTS		Weighted Average Price per Bbl
---	---	---	---	---
	Volume		Sold	Fair Value at
	(MBbls)	Swaps	Calls	December 31, 2023
2024
Swaps	3,301	$37.74	$—	$9,804
Stand-Alone Calls	915	—	31.29	(2,400)
2025
Swaps	2,143	$30.22	$—	$(1,411)
2026
Swaps	1,097	$27.68	$—	$(1,261)
Total NGLs contracts	7,456			$4,732	OIL CONTRACTS		Weighted Average Price per Bbl
---	---	---	---	---
	Volume		Sold	Fair Value at
	(MBbls)	Swaps	Calls	December 31, 2023
2024
Swaps	431	$62.54	$—	$(3,521)
Sold Calls	183	—	70.00	(1,188)
2025
Swaps	366	$59.01	$—	$(3,057)
2026
Swaps	283	$59.48	$—	$(1,451)
2027
Swaps	162	$58.60	$—	$(677)
Total oil contracts	1,425			$(9,894)	INTEREST	Principal<br><br>Hedged		Fair Value at
---	---	---	---
		Fixed-Rate	December 31, 2023
2023
SOFR Interest Rate Swap	$5,520	4.15%	315
Net fair value of derivative financial instruments as of December 31, 2023			$(557,460)

Netting the fair values of derivative assets and liabilities for financial reporting purposes is permitted if such assets and

liabilities are with the same counterparty and a legal right of set-off exists, subject to a master netting arrangement. The

Directors have elected to present derivative assets and liabilities net when these conditions are met. The following table

outlines the Group’s net derivatives as of the periods presented:

Derivative Financial Instruments	Consolidated Statement of Financial<br><br>Position	December 31, 2023	December 31, 2022
Assets:
Non-current assets	Derivative financial instruments	$24,401	$13,936
Current assets	Derivative financial instruments	87,659	27,739
Total assets		$112,060	$41,675
Liabilities
Non-current liabilities	Derivative financial instruments	$(623,684)	$(1,177,801)
Current liabilities	Derivative financial instruments	(45,836)	(293,840)
Total liabilities		$(669,520)	$(1,471,641)
Net assets (liabilities):
Net assets (liabilities) - non-current	Other non-current assets (liabilities)	$(599,283)	$(1,163,865)
Net assets (liabilities) - current	Other current assets (liabilities)	41,823	(266,101)
Total net assets (liabilities)		$(557,460)	$(1,429,966)

The Group presents the fair value of derivative contracts on a net basis in the consolidated statement of financial position. The

following presents the impact of this presentation on the Group’s recognized assets and liabilities as of the periods indicated:

206	Diversified Energy Company plc Annual Report and Form 20-F2023
	December 31, 2023
---	---	---	---
	Presented without<br><br>Effects of Netting	Effects of Netting	As Presented with<br><br>Effects of Netting
Non-current assets	$103,008	$(78,607)	$24,401
Current assets	198,806	(111,147)	87,659
Total assets	$301,814	$(189,754)	$112,060
Non-current liabilities	(678,053)	54,369	(623,684)
Current liabilities	(181,221)	135,385	(45,836)
Total liabilities	$(859,274)	$189,754	$(669,520)
Total net assets (liabilities)	$(557,460)	$—	$(557,460)	December 31, 2022
---	---	---	---
	Presented without<br><br>Effects of Netting	Effects of Netting	As Presented with<br><br>Effects of Netting
Non-current assets	$101,275	$(87,339)	$13,936
Current assets	92,611	(64,872)	27,739
Total assets	$193,886	$(152,211)	$41,675
Non-current liabilities	(1,261,369)	83,568	(1,177,801)
Current liabilities	(362,483)	68,643	(293,840)
Total liabilities	$(1,623,852)	$152,211	$(1,471,641)
Total net assets (liabilities)	$(1,429,966)	$—	$(1,429,966)

The Group recorded the following gain (loss) on derivative financial instruments in the Consolidated Statement of

Comprehensive Income for the periods presented:

	Year Ended
	December 31, 2023	December 31, 2022	December 31, 2021
Net gain (loss) on commodity derivatives settlements(a)	$178,064	$(895,802)	$(320,656)
Net gain (loss) on interest rate swaps(a)	(2,722)	(1,434)	(530)
Gain (loss) on foreign currency hedges(a)	(521)	—	(1,227)
Total gain (loss) on settled derivative instruments	$174,821	$(897,236)	$(322,413)
Gain (loss) on fair value adjustments of unsettled financial<br><br>instruments(b)	905,695	(861,457)	(652,465)
Total gain (loss) on derivative financial instruments	$1,080,516	$(1,758,693)	$(974,878)

(a)Represents the cash settlement of hedges that settled during the period.

(b)Represents the change in fair value of financial instruments net of removing the carrying value of hedges that settled during the period.

All derivatives are defined as Level 2 instruments as they are valued using inputs and outputs other than quoted prices that are

observable for the assets and liabilities.

Commodity Derivative Contract Modifications and Extinguishments

From time to time, such as when acquiring producing assets, completing ABS financings or navigating changing price

environments, the Group will opportunistically modify, offset, extinguish or add to certain existing hedge positions.

Modifications include the volume of production subject to contracts, the swap or strike price of certain derivative contracts

and similar elements of the derivative contract. The Group maintains distinct, long-dated derivative contract portfolios for its

ABS financings and Term Loan I. The Group also maintains a separate derivative contract portfolio related to its assets

collateralized by the Credit Facility. The derivative contract portfolios for the Group’s ABS financings, Term Loan 1 and Credit

Facility are reflected in the Group’s Statement of Financial Position.

2023 Modifications and Extinguishments

In February 2023, the Group sold puts in ABS III for approximately $9,045 and replaced them with swaps to maintain the

appropriate level and composition of derivatives at both the legal entity and full-company level. In August 2023, the Group

monetized $9,240 in purchased puts associated with its ABS hedge books and transitioned the monetized positions into long-

dated swap agreements. The Group also monetized an additional $8,401 in net modifications, primarily comprised of swap

terminations. As these modifications were made in the normal course of business for the year ended December 31, 2023, they

are presented as an operating activity in the Consolidated Statement of Cash Flows.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	207

In November 2023, the Group adjusted portions of its commodity derivative portfolio across its legal entities to ensure that it

maintained the appropriate level and composition at both the legal entity and full-Group level for the completion of the ABS

VII financing arrangement. These portfolio adjustments included novations of certain contracts to the legal entities holding the

ABS VII Notes. The Group paid $6,376 for these portfolio adjustments. As these modifications were associated with a

borrowing transaction, these amounts are presented as a financing activity in the Consolidated Statement of Cash Flows.

Refer to Note 21 for additional information regarding ABS financing arrangements.

2022 Modifications and Extinguishments

In February 2022, the Group adjusted portions of its commodity derivative portfolio across its legal entities to ensure that it

maintained the appropriate level and composition at both the legal entity and full-Group level for the completion of the ABS III

and ABS IV financing arrangements. The Group completed these adjustments by entering into new commodity derivative

contracts and novating certain derivative contracts to the legal entities holding the ABS III and ABS IV notes. The Group paid

$41,823 for these portfolio adjustments, driven primarily by the purchase of long-dated puts for ABS III and ABS IV that

collectively increased the value of the Group’s derivative position by an equal amount, and were required under the respective

ABS III and ABS IV indentures. The Group recorded payments for offsetting positions as new derivative financial instruments

and applied extinguishment payments against the existing commodity contracts in its Consolidated Statement of

Financial Position.

In May 2022, and in October 2022 the Group completed the ABS V and ABS VI financing arrangements, respectively, and

made similar commodity derivative portfolio adjustments to maintain the appropriate level and composition of derivatives at

both the legal entity and full-Group level. The Group paid $31,250, driven primarily by the purchase of long-dated puts that

increased the value of the Group’s derivative position by an equal amount, and were required under the ABS V indenture.

Under the ABS VI financing, the Group paid $32,242 from the proceeds of the financing to increase the value of certain pre-

existing derivative contracts that were novated to the ABS VI legal entity at closing. The Group recorded the payments as new

derivative financial instruments in its Consolidated Statement of Financial Position.

Refer to Note 21 for additional information regarding ABS financing arrangements.

Other commodity derivative contract modifications made during the normal course of business for the year ended December

31, 2022 totaled $133,573 which the Group recorded in its Consolidated Statement of Financial Position. As these modifications

were made in the normal course, the Group has presented these as an operating activity in the Consolidated Statement of

Cash Flows. These modifications were primarily associated with elevating the Group’s weighted average hedge floor to take

advantage of the high price environment experienced in 2022 over a longer term. The trades were primarily comprised of

swap enhancements and the extinguishment of standalone call options.

2021 Modifications and Extinguishments

In August 2021 as part of the Tanos acquisition, the Group obtained the option to novate or extinguish the Tanos hedge book.

In conjunction with the closing settlement, DEC elected to extinguish their share of the Tanos hedge book. The cost to

terminate was $52,666. This payment relieved the termination liability established on the Group’s Consolidated Statement of

Financial Position in purchase accounting and has been presented as an investing activity in the Consolidated Statement of

Cash Flows given its connection to the Tanos acquisition. New derivative contracts were subsequently entered into for more

favorable pricing in order to secure the cash flows associated with these producing assets in an elevated price environment.

In May 2021, subsequent to the close of the Indigo acquisition, market dynamics began shifting to a more favorable commodity

price environment. Given the favorable forward curve, the Group elected to early terminate certain legacy Indigo derivative

positions resulting in a cash payment of $6,797 which the Group recorded in its Consolidated Statement of Financial Position.

Since this extinguishment occurred subsequent to the acquisition date the Group has presented this payment as an operating

activity in the Consolidated Statement of Cash Flows. New derivative contracts were subsequently entered into for more

favorable pricing in order to secure the cash flows associated with these producing assets in an elevated price environment.

Refer to Note 5 for additional information regarding acquisitions.

Other commodity derivative contract modifications made during the normal course of business for the year ended December

31, 2021 totaled $3,367 which the Group recorded in its Consolidated Statement of Financial Position. As these modifications

were made in the normal course of business, the Group has presented these as an operating activity in the Consolidated

Statement of Cash Flows.

NOTE 14 - TRADE AND OTHER RECEIVABLES

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

Trade receivables include amounts due from customers, entities that purchase the Group’s natural gas, NGLs and oil

production, and also include amounts due from joint interest owners, entities that own a working interest in the properties

operated by the Group. The majority of trade receivables are current, and the Group believes these receivables are collectible.

The following table summarizes the Group’s trade receivables. The fair value approximates the carrying value as of the

periods presented:

208	Diversified Energy Company plc Annual Report and Form 20-F2023
	December 31, 2023	December 31, 2022
---	---	---
Commodity receivables(a)	$172,045	$285,700
Other receivables(b)	34,691	20,022
Total trade receivables	$206,736	$305,722
Allowance for credit losses(c)	(16,529)	(8,941)
Total trade receivables, net	$190,207	$296,781

(a)Includes trade receivables and accrued revenues. The decrease in commodity receivables primarily reflects the decrease in commodity

pricing over the course of 2023.

(b)Other receivables consist primarily of joint interest receivables in 2023 and 2022.

(c)The allowance for credit losses is primarily related to amounts due from joint interest owners. Year-over-year increases is primarily due to

the declining commodity pricing environment during the year.

NOTE 15 - OTHER ASSETS

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

The following table includes details of other assets as of the periods presented:

	December 31, 2023	December 31, 2022
Other non-current assets
Other non-current assets(a)	$9,172	$4,351
Total other non-current assets	$9,172	$4,351
Other current assets
Prepaid expenses	$3,955	$5,255
Inventory	7,829	9,227
Total other current assets	$11,784	$14,482

(a)Includes the Group’s investment in DP Lion Equity Holdco LLC of $7,500 as of December 31, 2023. Refer to Notes 5 and 21 for additional

information regarding the DP Lion Equity Holdco LLC equity sale.

NOTE 16 - SHARE CAPITAL

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

The Company has one class of common shares which carry the right to one vote at annual general meetings of the Group. As

of December 31, 2023, the Group had no limit on the amount of authorized share capital and all shares in issue were fully paid.

Effective December 5, 2023, the Company executed a 20-for-1 consolidation of its outstanding shares. The Company’s issued

share capital has been retrospectively adjusted for all reporting periods.

Share capital represents the nominal (par) value of shares (£0.20) that have been issued. Share premium includes any

premiums received on issue of share capital above par. Any transaction costs associated with the issuance of shares are

deducted from share premium, net of any related income tax benefits. The components of share capital include:

Issuance of Share Capital

In February 2023, the Group placed 6,422 new shares at $25.34 per share (£21.00) to raise gross proceeds of $162,757

(approximately £134,866). Associated costs of the placing were $5,969. The Group used the proceeds to fund the Tanos II

transaction, discussed in Note 5.

In 2022, there were no issuances of share capital for purposes other than share-based compensation awards issued at par

which were insignificant for the period.

In May 2021, the Group placed 7,077 new shares at $31.80 per share (£22.40) to raise gross proceeds of $225,050

(approximately £158,526). Associated costs of the placing were $11,206. The Group used the proceeds to pay down the Credit

Facility and partially fund the Indigo and Blackbeard acquisitions, discussed in Notes 21 and 5, respectively.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	209

Treasury Shares

The Group’s holdings in its own equity instruments are classified as treasury shares. The consideration paid, including any

directly attributable incremental costs, is deducted from the stockholders’ equity of the Group until the shares are cancelled or

reissued. No gain or loss is recognized in the income statement on the purchase, sale, issue or cancellation of treasury shares.

EMPLOYEE BENEFIT TRUST (“EBT”)

In March 2022, the Group established the EBT for the benefit of the employees of the Group. The Group funds the EBT to

facilitate the acquisition of shares. The shares in the EBT are held to satisfy awards and grants under the Group’s 2017 Equity

Incentive Plan and the Employee Share Purchase Plan (the “ESPP”). Shares held in the EBT are accounted for in the same

manner as treasury shares and are therefore included in the Consolidated Financial Statement as treasury shares.

During the year ended December 31, 2023, the EBT issued 334 shares to settle vested share-based awards and ESPP

purchases. No shares were purchased by the EBT during the year ended December 31, 2023. During the year ended

December 31, 2022, the EBT purchased 790 shares at an average price per share of $29.04 (approximately £24.56) for a total

consideration of $22,931 (approximately £19,388). During the year ended December 31, 2022, the EBT issued 88 to settle

vested share-based awards. As of December 31, 2023, the EBT held 367 shares. Refer to Note 17 for additional information

related to share-based compensation.

REPURCHASE OF SHARES

During the year ended December 31, 2023, the Group repurchased 647 treasury shares at an average price of $17.08 totaling

$11,048, representing 1% of issued share capital as of December 31, 2023. During the year ended December 31, 2022, the Group

repurchased 400 treasury shares at an average price of $29.42 totaling $11,760, representing 1% of issued share capital as of

December 31, 2022.

The Group has accounted for the repurchase of these shares as a reduction to the treasury reserve. All repurchased treasury

shares were cancelled upon repurchase and as of December 31, 2023 and 2022, their par value of $161 and $80, respectively,

was retired into the capital redemption reserve included within share based payments and other reserves in the Consolidated

Statement of Financial Position.

SETTLEMENT OF WARRANTS

In July 2022, the Group entered into an agreement to cancel 7 warrants (the "Warrants") held by certain former Mirabaud

Securities Limited ("Mirabaud") employees for an aggregate principal amount of approximately $56 (approximately £46). The

former employees surrendered the Warrants to the Group for cancellation. Concurrently, the Group entered into an agreement

to exercise 11 Warrants held by certain former Mirabaud employees for an aggregate principal amount of approximately $201

(approximately £166). The former employees surrendered the Warrants to the Group for cancellation in exchange for an

equivalent number of shares of common stock. Following this purchase and exercise, no warrants remain outstanding.

In February 2022, the Group entered into an agreement to cancel 24 Warrants held by certain former Mirabaud Securities

Limited ("Mirabaud") employees for an aggregate principal amount of approximately $265 (approximately £196). The former

employees surrendered the Warrants to the Group for cancellation. Concurrently, the Group entered into an agreement to

exercise 15 Warrants held by certain former Mirabaud employees for an aggregate principal amount of approximately $251

(approximately £187). The former employees surrendered the Warrants to the Group for cancellation in exchange for an

equivalent number of shares of common stock. Following this purchase and exercise, 18 warrants remained outstanding.

In January 2021, the Group entered into an agreement to cancel 119 Warrants held by Mirabaud and certain former Mirabaud

employees for an aggregate principal amount of approximately $1,429 (approximately £1,040). Mirabaud and its former

employees surrendered the Warrants to the Group for cancellation. Following this purchase, 57 warrants

remained outstanding.

210	Diversified Energy Company plc Annual Report and Form 20-F2023

The following tables summarize the Group's share capital, net of customary transaction costs, for the periods presented:

	Number of Shares	Total Share Capital	Total Share Premium
Balance as of December 31, 2020	35,369	$9,520	$841,159
Issuance of share capital (equity placement)	7,077	2,044	211,800
Issuance of share capital (equity compensation)	37	7	—
Balance as of December 31, 2021	42,483	$11,571	$1,052,959
Issuance of share capital (settlement of warrants)	26	5	—
Issuance of share capital (equity compensation)	40	7	—
Issuance of EBT shares (equity compensation)	88	—	—
Repurchase of shares (EBT)	(790)	—	—
Repurchase of shares (share buyback program)	(400)	(80)	—
Balance as of December 31, 2022	41,447	$11,503	$1,052,959
Issuance of share capital (equity placement)	6,422	1,555	155,233
Issuance of EBT shares (equity compensation)	334	—	—
Repurchase of shares (share buyback program)	(647)	(161)	—
Balance as of December 31, 2023	47,556	12,897	1,208,192

NOTE 17 - NON-CASH SHARE-BASED COMPENSATION

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

Equity Incentive Plan

The 2017 Equity Incentive Plan (the “Plan”), as amended through April 27, 2021, authorized and reserved for issuance 3,284

shares of common stock, which may be issued upon exercise of vested Options or the vesting of RSUs, PSUs and dividend

equivalent units (“DEUs”) that are granted under the Plan. As of December 31, 2023, 1,648 shares have vested and been issued

to Plan participants, 1,141 shares have been granted but remain unvested and 238 DEUs have accrued and remain unvested. As

of December 31, 2022, 595 shares had vested and been issued to Plan participants, 1,283 shares had been granted but

remained unvested and 212 DEUs had accrued and remained unvested. Refer to the Remuneration Committee’s Report within

this Annual Report & Form 20-F for additional information regarding the terms of awards issued under the Plan.

Effective December 5, 2023, the Company executed a 20-for-1 consolidation of its outstanding shares. The Group’s share-

based payment awards have been retroactively adjusted for all reporting periods.

Options Awards

The following table summarizes Options award activity for the respective periods presented:

	Number of Options(a)	Weighted Average<br><br>Grant Date Fair<br><br>Value per Share
Balance as of December 31, 2020	1,151	$8.50
Granted	—	—
Exercised(b)	(41)	6.60
Forfeited	(15)	11.80
Balance as of December 31, 2021	1,095	$8.53
Granted	—	—
Exercised(b)	(399)	6.60
Forfeited	(320)	11.30
Balance as of December 31, 2022	376	$8.21
Granted	—	—
Exercised(b)	(2)	6.60
Forfeited	(153)	8.25
Balance as of December 31, 2023	221	$8.20

(a)As of December 31, 2023, 2022 and 2021, 162, 19 and 202 Options were exercisable, respectively. As of December 31, 2023 all remaining

Options outstanding have an exercise price ranging from £16.80 to £24.00 and a weighted average remaining contractual life of 4.6 years.

(b)The weighted average exercise date share price was $24.29, $32.35 and $34.80 for Options exercised during 2023, 2022 and 2021,

respectively.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	211

The Group’s Options ratably vest over a three-year period and contain both performance and service metrics. The

performance metrics include Adjusted EPS as compared to pre-established benchmarks and a calculation that compares the

Group’s TSR to pre-established benchmarks. The number of units that will vest can range between 0% and 100% of the award.

The fair value of the Group’s Options was calculated using the Black-Scholes model as of the grant date and is uniformly

expensed over the vesting period. No Options were awarded during the years ended December 31, 2023, 2022 and 2021.

RSU Awards

The following table summarizes RSU equity award activity for the respective periods presented:

	Number of Shares	Weighted Average<br><br>Grant Date Fair Value<br><br>per Share
Balance as of December 31, 2020	172	$23.76
Granted	77	31.72
Vested	(38)	23.27
Forfeited	(4)	26.38
Balance as of December 31, 2021	207	$26.76
Granted	199	27.70
Vested	(64)	25.92
Forfeited	(4)	27.24
Balance as of December 31, 2022	338	$27.47
Granted	253	22.35
Vested	(181)	23.08
Forfeited	(102)	27.54
Balance as of December 31, 2023	308	$25.82

RSUs cliff- or ratably-vest based on service conditions. The fair value of the Group’s RSUs is determined using the stock price

at the grant date and uniformly expensed over the vesting period.

PSU Awards

The following table summarizes PSU equity award activity for the respective periods presented:

	Number of Shares	Weighted Average<br><br>Grant Date Fair Value<br><br>per Share
Balance as of December 31, 2020	221	$25.15
Granted	124	21.64
Vested	—	—
Forfeited	(4)	23.06
Balance as of December 31, 2021	341	$23.90
Granted	232	28.04
Vested	—	—
Forfeited	(4)	26.07
Balance as of December 31, 2022	569	$25.57
Granted	349	16.66
Vested	(216)	23.85
Forfeited	(90)	20.30
Balance as of December 31, 2023	612	$21.87

PSUs cliff-vest based on performance criteria which include a three-year average adjusted return on equity as compared to

pre-established benchmarks, a calculation that compares the Group’s TSR to pre-established benchmarks as well as the same

calculated return for a group of peer companies as selected by the Group, and methane intensity reduction over three years.

The number of units that will vest can range between 0% and 100% of the award.

The fair value of the Group’s PSUs is calculated using a Monte Carlo simulation model as of the grant date and is uniformly

expensed over the vesting period. The inputs to the Monte Carlo model included the following for PSUs granted during the

respective periods presented:

212	Diversified Energy Company plc Annual Report and Form 20-F2023
	December 31, 2023	December 31, 2022	December 31, 2021
---	---	---	---
Risk-free rate of interest	3.3%	1.3%	0.2%
Volatility(a)	31%	37%	35%
Correlation with comparator group range	0.01 - 0.30	0.01 - 0.36	0.02 - 0.36

(a)Volatility utilizes the historical volatility for the Group’s share price.

Employee Stock Purchase Plan

The Employee Stock Purchase Plan (the “ESPP”), implemented in February 2023, authorized and reserved for issuance 300

shares of common stock. As of December 31, 2023, 15 shares have been purchased by and issued to ESPP participants, and

285 shares remain available to be purchased.

Share-Based Compensation Expense

The following table presents the share-based compensation expense for the respective periods presented:

	December 31, 2023	December 31, 2022	December 31, 2021
Options	$292	$(749)	$2,115
RSUs	2,833	4,210	2,346
PSUs	3,335	4,590	2,939
ESPP	34	—	—
Total share-based compensation expense	$6,494	$8,051	$7,400

NOTE 18 - DIVIDENDS

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

Effective December 5, 2023, the Company executed a 20-for-1 consolidation of its outstanding shares. Prices per share and

shares outstanding have been retroactively adjusted for all reporting periods.

The following table summarizes the Group's dividends declared and paid on the dates indicated:

	Dividend per Share		Pay Date	Shares<br><br>Outstanding	Gross<br><br>Dividends<br><br>Paid
Date Dividends Declared	USD
November 14, 2022	$0.8750	0.7220	March 28, 2023	47,869	$41,885
March 21, 2023	$0.8750	0.6860	June 30, 2023	48,165	42,144
May 9, 2023	$0.8750	0.7040	September 29, 2023	48,157	42,137
September 1, 2023	$0.8750	0.6840	December 29, 2023	47,857	41,875
Paid during the year ended December 31, 2023					$168,041
October 28, 2021	$0.8500	0.6500	March 28, 2022	42,502	$36,127
March 22, 2022	$0.8500	0.6860	June 30, 2022	42,527	36,148
May 16, 2022	$0.8500	0.7320	September 26, 2022	42,294	35,950
August 8, 2022	$0.8500	0.6900	December 28, 2022	41,447	35,230
Paid during the year ended December 31, 2022					$143,455
October 29, 2020	$0.8000	0.5700	March 26, 2021	35,376	$28,301
March 8, 2021	$0.8000	0.5620	June 24, 2021	42,472	33,970
April 30, 2021	$0.8000	0.5760	September 24, 2021	42,480	33,984
August 5, 2021	$0.8000	0.5980	December 17, 2021	42,480	33,984
Paid during the year ended December 31, 2021					$130,239

All values are in British Pounds.

On November 15, 2023 the Group proposed a dividend of $0.8750 per share. The dividend will be paid on March 28, 2024 to

shareholders on the register on March 1, 2024. This dividend was not approved by shareholders, thereby qualifying it as an

“interim” dividend. No liability was recorded in the Group Financial Statements in respect of this interim dividend as of

December 31, 2023.

Dividends are waived on shares held in the EBT.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	213

Subsequent Events

On March 19, 2024 the Directors recommended a dividend of $0.29 per share. The dividend will be subject to shareholder

approval at the AGM. Provided this dividend was not approved by shareholders as of the reporting date, this represents an

“interim” dividend. No liability has been recorded in the Group Financial Statements in respect of this dividend as of

December 31, 2023.

NOTE 19 - ASSET RETIREMENT OBLIGATIONS

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

The Group records a liability for the present value of the estimated future decommissioning costs on its natural gas and oil

properties, Although productive life varies within our well portfolio, presently we expect all of our existing wells to have

reached the end of their productive lives and be retired by approximately 2095, consistent with our reserve calculations which

were independently evaluated by third-party engineers. The Group also records a liability for the future cost of

decommissioning its production facilities and pipelines when required by contract, statute, or constructive obligation. No state

contractual agreements or statutes for production facilities and pipelines would impose material obligations on the Group for

the years ended December 31, 2023, 2022 and 2021.

In estimating the present value of future decommissioning costs of natural gas and oil properties the Group takes into account

the number and state jurisdictions of wells, current costs to decommission by state and well type, and the Group’s retirement

plan which is based on state requirements and the Group’s retirement capacity over the producing lives of the Group’s well

portfolio. The Directors’ assumptions are based on the current economic environment and represent what the Directors

believe is a reasonable basis upon which to estimate the future liability. However, actual decommissioning costs will ultimately

depend upon future market prices at the time the decommissioning services are performed. Furthermore, the timing of

decommissioning will vary depending on when the fields cease to produce economically, making the determination dependent

upon future natural gas and oil prices, which are inherently uncertain.

The Group applies a contingency allowance for annual inflationary cost increases to its current cost expectations then

discounts the resulting cash flows using a credit adjusted risk free discount rate. The inflationary adjustment is a U.S. long-term

10-year rate sourced from consensus economics. When determining the discount rate of the liability, the Group evaluates

treasury rates as well as the Bloomberg 15-year U.S. Energy BB and BBB bond index which economically aligns with the

underlying long-term and unsecured liability. Based on this evaluation the net discount rate used in the calculation of the

decommissioning liability in 2023, 2022 and 2021 was 3.4%, 3.6% and 2.9%, respectively.

The composition of the provision for asset retirement obligations at the reporting date was as follows for the

periods presented:

	Year Ended
	December 31, 2023	December 31, 2022	December 31, 2021
Balance at beginning of period	$457,083	$525,589	$346,124
Additions(a)	3,250	24,395	96,292
Accretion	26,926	27,569	24,396
Asset retirement costs	(5,961)	(4,889)	(2,879)
Disposals(b)	(17,300)	(16,779)	(16,500)
Revisions to estimate(c)	42,650	(98,802)	78,156
Balance at end of period	$506,648	$457,083	$525,589
Less: Current asset retirement obligations	5,402	4,529	3,399
Non-current asset retirement obligations	$501,246	$452,554	$522,190

(a)Refer to Note 5 for additional information regarding acquisitions and divestitures.

(b)Associated with the divestiture of natural gas and oil properties. Refer to Note 10 for additional information.

(c)As of December 31, 2023, we performed normal revisions to our asset retirement obligations, which resulted in a $42,650 increase in the

liability. This increase was comprised of a $27,830 increase attributable to a lower discount rate as a result of slightly decreased bond yields

as compared to 2022 as inflation began to increase at a lower rate and a $16,059 increase for cost revisions based on our recent asset

retirement experiences. Partially offsetting this increase was a $1,239 change attributed to retirement timing. As of December 31, 2022, the

Group performed normal revisions to its asset retirement obligations, which resulted in a $98,802 decrease in the liability. This decrease was

comprised of a $144,656 decrease attributable to a higher discount rate. The higher discount rate was a result of macroeconomic factors

spurred by the increase in bond yields which have elevated with U.S. treasuries to combat the current inflationary environment. Partially

offsetting this decrease was $29,357 in cost revisions based on the Group’s recent asset retirement experiences and a $16,497 timing

revision for the acceleration of the Group’s retirement plans made possible by asset retirement acquisitions that improved the Group’s asset

retirement capacity through the growth of its operational capabilities. As of December 31, 2021, the Group performed normal revisions to its

asset retirement obligations, which resulted in a $78,156 increase in the liability. This increase was comprised of a $109,306 increase

attributable to the lower discount rate which was then offset by a $27,038 decrease for cost revisions based on our recent asset retirement

experiences. The remaining change was attributable to timing. The lower discount rate was a result of macroeconomic factors spurred by

the COVID-19 recovery, which reduced bond yields and increased inflation. Cost reductions are a result of our recent asset retirement

experiences.

214	Diversified Energy Company plc Annual Report and Form 20-F2023

Changes to assumptions for the estimation of the Group’s asset retirement obligations could result in a material change in the

carrying value of the liability. A reasonably possible change in assumptions could have the following impact on the Group’s

asset retirement obligations as of December 31, 2023:

ARO Sensitivity	Scenario 1(a)	Scenario 2(b)
Discount rate	$(164,357)	$817,004
Timing	31,339	(34,235)
Cost	50,580	(50,580)

(a)Scenario 1 assumes an increase of the BBB 15 year discount rate to approximately 7% (which is one of the highest rates observed since

2020), a 10% increase in cost and a 10% increase in timing by assuming the addition of one plugging rig, which would accelerate retirement

plans. All of these scenarios have been either historically observed or are considered reasonably possible.

(b)Scenario 2 assumes a decrease of the BBB 15 year discount rate to approximately 3% (which is one of the lowest rates observed since 2020),

a 10% decrease in cost and a 10% decrease in timing by assuming the loss of one plugging rig, which would delay retirement plans. All of

these scenarios have been either historically observed or are considered reasonably possible.

NOTE 20 - LEASES

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

The Group leased automobiles, equipment and real estate for the periods presented below. A reconciliation of leases arising

from financing activities and the balance sheet classification of future minimum lease payments as of the reporting periods

presented were as follows:

	Present Value of<br><br>Minimum Lease Payments
	December 31, 2023	December 31, 2022	December 31, 2021
Balance at beginning of period	$28,862	$27,804	$18,878
Additions(a)	14,430	11,269	16,482
Interest expense(b)	1,661	1,022	1,050
Cash outflows	(13,831)	(11,233)	(8,606)
Balance at end of period	$31,122	$28,862	$27,804
Classified as:
Current liability	$10,563	$9,293	$9,627
Non-current liability	20,559	19,569	18,177
Total	$31,122	$28,862	$27,804

(a)The $14,430 and $11,269 in lease additions during the years ended December 31, 2023 and December 31, 2022, respectively, was primarily

attributable to the expansion of the Group’s fleet due to continued growth. Of the $16,482 in lease additions during the year ended

December 31, 2021, $8,062 was attributable to the Indigo, Blackbeard and Tapstone acquisitions. Refer to Note 5 for additional information

regarding acquisitions.

(b)Included as a component of finance cost.

Set out below is the movement in the right-of-use assets:

	Right-of-Use Assets
	December 31, 2023	December 31, 2022	December 31, 2021
Balance at beginning of period	$27,959	$26,908	$18,026
Additions(a)	13,279	11,295	16,554
Depreciation	(11,224)	(10,244)	(7,672)
Balance at end of period	$30,014	$27,959	$26,908
Classified as:
Motor vehicles	$25,592	$23,782	$19,149
Midstream	3,136	3,801	6,502
Buildings and leasehold improvements	1,286	376	1,257
Total	$30,014	$27,959	$26,908

(a)The $13,279 and $11,295 in lease additions during the years ended December 31, 2023 and December 31, 2022, respectively, was attributable

to the expansion of the Group’s fleet due to continued growth. Of the $16,554 in lease additions during the year ended December 31, 2021,

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	215

$8,062 was attributable to the Indigo, Blackbeard and Tapstone acquisitions. Refer to Note 5 for additional information regarding

acquisitions.

The range of discount rates applied in calculating right-of-use assets and related lease liabilities, depending on the lease term,

is presented below:

	December 31, 2023	December 31, 2022	December 31, 2021
Discount rates range	1.8% - 7.1%	1.8% - 6.3%	1.8% - 3.3%

Expenses related to short-term and low-value lease exemptions applied under IFRS 16 are primarily associated with short term

compressor rentals and were $30,024, $25,153 and $15,362 for the years ended December 31, 2023 and 2022 and 2021,

respectively. These amounts have been included in the Group’s operating expenses and are primarily concentrated in LOE.

The following table reflects the maturity of leases as of the periods presented:

	December 31, 2023	December 31, 2022	December 31, 2021
Not Later Than One Year	$10,563	$9,293	$9,627
Later Than One Year and Not Later Than Five Years	20,559	19,569	18,177
Later Than Five Years	—	—	—
Total	$31,122	$28,862	$27,804

NOTE 21 - BORROWINGS

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

The Group’s borrowings consist of the following amounts as of the reporting date:

	December 31, 2023	December 31, 2022
Credit Facility (Interest rate of 8.66% and 7.42%, respectively)(a)	$159,000	$56,000
ABS I Notes (Interest rate of 5.00%)	100,898	125,864
ABS II Notes (Interest rate of 5.25%)	125,922	147,458
ABS III Notes (Interest rate of 4.875%)	274,710	319,856
ABS IV Notes (Interest rate of 4.95%)	99,951	130,144
ABS V Notes (Interest rate of 5.78%)	290,913	378,796
ABS VI Notes (Interest rate of 7.50%)	159,357	212,446
Term Loan I (Interest rate of 6.50%)	106,470	120,518
Miscellaneous, primarily for real estate, vehicles and equipment	7,627	7,084
Total borrowings	$1,324,848	$1,498,166
Less: Current portion of long-term debt	(200,822)	(271,096)
Less: Deferred financing costs	(41,123)	(48,256)
Less: Original issue discounts	(7,098)	(9,581)
Total non-current borrowings, net	$1,075,805	$1,169,233

(a)Represents the variable interest rate as of period end.

Credit Facility

The Group maintains a revolving loan facility (the “Credit Facility”) with a lending syndicate, the borrowing base for which is

redetermined on a semi-annual, or as needed, basis. The Group’s wholly-owned subsidiary, DP RBL Co LLC, is the borrower

under the Credit Facility. The borrowing base is primarily a function of the value of the natural gas and oil properties that

collateralize the lending arrangement and will fluctuate with changes in collateral, which may occur as a result of acquisitions

or through the establishment of ABS, term loan or other lending structures that result in changes to the collateral base.

In August 2022, the Group amended and restated the credit agreement governing its Credit Facility. The amendment

enhanced the alignment with the Group’s stated ESG initiatives by including sustainability performance targets (“SPTs”) similar

to those included in the ABS III, IV, V and VI notes, extended the maturity of the Credit Facility to August 2026. In September

2023, the Group performed its semi-annual redetermination and the borrowing base was resized to $435,000. In November

2023, the borrowing base was resized to $305,000 to reflect the movement of collateral for the issuance of the ABS VII Notes.

Refer to Note 5 for additional information regarding the ABS VII transaction.

216	Diversified Energy Company plc Annual Report and Form 20-F2023

The Credit Facility has an interest rate of SOFR plus an additional spread that ranges from 2.75% to 3.75% based on utilization.

Interest payments on the Credit Facility are paid on a monthly basis. Available borrowings under the Credit Facility were

$134,817 as of December 31, 2023 which includes the impact of $11,183 in letters of credit issued to certain vendors.

The Credit Facility contains certain customary representations and warranties and affirmative and negative covenants,

including covenants relating to: maintenance of books and records; financial reporting and notification; compliance with laws;

maintenance of properties and insurance; and limitations on incurrence of indebtedness, liens, fundamental changes,

international operations, asset sales, making certain debt payments and amendments, restrictive agreements, investments,

restricted payments and hedging. The restricted payment provision governs the Group’s ability to make discretionary

payments such as dividends, share repurchases, or other discretionary payments. DP RBL Co LLC must comply with the

following restricted payments test in order to make discretionary payments (i) leverage is less than 1.5x and borrowing base

availability is >25% (ii) leverage is between 1.5x and 2.0x, free cash flow must be positive and borrowing base availability must

be >15% (iii) leverage is between 2.0x and 2.5x, free cash flow must be positive and borrowing base availability must be >20%

(iv) when leverage exceeds 2.5x for DP RBL Co LLC, restricted payments are prohibited.

Additional covenants require DP RBL Co LLC to maintain a ratio of total debt to EBITDAX of not more than 3.25 to 1.00 and a

ratio of current assets (with certain adjustments) to current liabilities of not less than 1.00 to 1.00 as of the last day of each

fiscal quarter. The fair value of the Credit Facility approximates the carrying value as of December 31, 2023.

Term Loan I

In May 2020, the Group acquired DP Bluegrass LLC (“Bluegrass”), a limited-purpose, bankruptcy-remote, wholly owned

subsidiary, to enter into a securitized financing agreement for $160,000, which was structured as a secured term loan. The

Group issued the Term Loan I at a 1% discount and used the proceeds of $158,400 to fund the 2020 Carbon and EQT

acquisitions. The Term Loan I is secured by certain producing assets acquired in connection with the Carbon and EQT

acquisitions.

The Term Loan I accrues interest at a stated 6.50% annual rate and has a maturity date of May 2030. Interest and principal

payments on the Term Loan I are payable on a monthly basis. During the years ended December 31, 2023, 2022 and 2021, the

Group incurred $7,573, $8,643 and $9,860 in interest related to the Term Loan I, respectively. The fair value of the Term Loan I

is approximately $101,706 as of December 31, 2023.

ABS I Note

In November 2019, the Group formed Diversified ABS LLC (“ABS I”), a limited-purpose, bankruptcy-remote, wholly-owned

subsidiary, to issue BBB- rated asset-backed securities for an aggregate principal amount of $200,000 at par. The ABS I Notes

are secured by certain of the Group’s upstream producing Appalachian assets. Natural gas production associated with these

assets was hedged at 85% at the close of the agreement with long-term derivative contracts.

Interest and principal payments on the ABS I Notes are payable on a monthly basis. During the years ended December 31,

2023, 2022 and 2021, the Group incurred $5,660, $7,110 and $8,460 of interest related to the ABS I Notes, respectively. The

legal final maturity date is January 2037 with an amortizing maturity of December 2029. The ABS I Notes accrue interest at a

stated 5% rate per annum. The fair value of the ABS I Notes is approximately $94,517 as of December 31, 2023.

In the event that ABS I has cash flow in excess of the required payments, ABS I is required to pay between 50% to 100% of the

excess cash flow, contingent on certain performance metrics, as additional principal, with the remaining excess cash flow, if

any, remaining with the Group. In particular, (a) with respect to any payment date prior to March 1, 2030, (i) if the debt service

coverage ratio (the “DSCR”) as of such payment date is greater than or equal to 1.25 to 1.00, then 25%, (ii) if the DSCR as of

such payment date is less than 1.25 to 1.00 but greater than or equal to 1.15 to 1.00, then 50%, and (iii) if the DSCR as of such

payment date is less than 1.15 to 1.00, the production tracking rate for ABS I is less than 80%, or the loan to value ratio is

greater than 85%, then 100%, and (b) with respect to any payment date on or after March 1, 2030, 100%. During the year ended

December 31, 2023, the Group paid $7,892 in excess cash flow payments on the ABS I Notes.

ABS II Note

In April 2020, the Group formed Diversified ABS Phase II LLC (“ABS II”), a limited-purpose, bankruptcy-remote, wholly owned

subsidiary, to issue BBB- rated asset-backed securities for an aggregate principal amount of $200,000. The ABS II Notes were

issued at a 2.775% discount. The Group used the proceeds of $183,617, net of discount, capital reserve requirement, and debt

issuance costs, to pay down its Credit Facility. The ABS II Notes are secured by certain of the Group’s upstream producing

Appalachian assets. Natural gas production associated with these assets was hedged at 85% at the close of the agreement

with long-term derivative contracts.

The ABS II Notes accrue interest at a stated 5.25% rate per annum and have a maturity date of July 2037 with an amortizing

maturity of September 2028. Interest and principal payments on the ABS II Notes are payable on a monthly basis. During the

years ended December 31, 2023, 2022 and 2021, the Group incurred $8,040, $9,286 and $10,530 in interest related to the ABS

II Notes, respectively. The fair value of the ABS II Notes is approximately $119,519 as of December 31, 2023.

In the event that ABS II has cash flow in excess of the required payments, ABS II is required to pay between 50% to 100% of

the excess cash flow, contingent on certain performance metrics, as additional principal, with the remaining excess cash flow, if

any, remaining with the Group. In particular, (a) (i) if the DSCR as of any payment date is less than 1.15 to 1.00, then 100%, (ii) if

the DSCR as of such payment date is greater than or equal to 1.15 to 1.00 and less than 1.25 to 1.00, then 50%, or (iii) if the

DSCR as of such payment date is greater than or equal to 1.25 to 1.00, then 0%; (b) if the production tracking rate for ABS II is

less than 80.0%, then 100%, else 0%; (c) if the loan-to-value ratio (“LTV”) as of such payment date is greater than 65.0%, then

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	217

100%, else 0%; (d) with respect to any payment date after July 1, 2024 and prior to July 1, 2025, if LTV is greater than 40.0%

and ABS II has executed hedging agreements for a minimum period of 30 months starting July 2026 covering production

volumes of at least 85% but no more than 95% (the “Extended Hedging Condition”), then 50%, else 0%; (e) with respect to any

payment date after July 1, 2025 and prior to October 1, 2025, if LTV is greater than 40.0% or ABS II has not satisfied the

Extended Hedging Condition, then 50%, else 0%; and (f) with respect to any payment date after October 1, 2025, if LTV is

greater than 40.0% or ABS II has not satisfied the Extended Hedging Condition, then 100%, else 0%. During the year ended

December 31, 2023, the Group made no excess cash flow payments on the ABS II Notes.

ABS III Note

In February 2022, the Group formed Diversified ABS III LLC (“ABS III”), a limited-purpose, bankruptcy-remote, wholly-owned

subsidiary, to issue BBB rated asset-backed securities for an aggregate principal amount of $365,000 at par. The ABS III Notes

are secured by certain of the Group’s upstream producing, as well as certain midstream, Appalachian assets.

The ABS III Notes accrue interest at a stated 4.875% rate per annum and have a final maturity date of April 2039 with an

amortizing maturity of November 2030. Interest and principal payments on the ABS III Notes are payable on a monthly basis.

During the years ended December 31, 2023 and 2022, the Group incurred $14,515 and $15,325 in interest related to the ABS III

Notes, respectively. The fair value of the ABS III Notes is approximately $250,158 as of December 31, 2023.

In the event that ABS III has cash flow in excess of the required payments, ABS III is required to pay between 50% to 100% of

the excess cash flow, contingent on certain performance metrics, as additional principal, with the remaining excess cash flow, if

any, remaining with the Group. In particular, (a) (i) if the DSCR as of any payment date is greater than or equal to 1.25 to 1.00,

then 0%, (ii) if the DSCR as of such payment date is less than 1.25 to 1.00 but greater than or equal to 1.15 to 1.00, then 50%,

and (iii) if the DSCR as of such Payment Date is less than 1.15 to 1.00, then 100%; (b) if the production tracking rate for ABS III

(as described in the ABS III Indenture) is less than 80%, then 100%, else 0%; and (c) if the LTV for ABS III is greater than 65%,

then 100%, else 0%. During the year ended December 31, 2023, the Group made no excess cash flow payments on the

ABS III Notes.

ABS IV Note

In February 2022, the Group formed Diversified ABS IV LLC (“ABS IV”), a limited-purpose, bankruptcy-remote, wholly-owned

subsidiary, to issue BBB rated asset-backed securities for an aggregate principal amount of $160,000 at par. The ABS IV Notes

are secured by a portion of the upstream producing assets acquired in connection with the Blackbeard Acquisition.

The ABS IV Notes accrue interest at a stated 4.95% rate per annum and have a final maturity date of February 2037 with an

amortizing maturity of September 2030. Interest and principal payments on the ABS IV Notes are payable on a monthly basis.

During the year ended December 31, 2023 and 2022, the Group incurred $5,703 and $6,235 in interest related to the ABS IV

Notes, respectively. The fair value of the ABS IV Notes is approximately $92,345 as of December 31, 2023.

In the event that ABS IV has cash flow in excess of the required payments, ABS IV is required to pay between 50% to 100% of

the excess cash flow, contingent on certain performance metrics, as additional principal, with the remaining excess cash flow, if

any, remaining with the Group. In particular, (a) (i) if the DSCR as of any payment date is greater than or equal to 1.25 to 1.00,

then 0%, (ii) if the DSCR as of such payment date is less than 1.25 to 1.00 but greater than or equal to 1.15 to 1.00, then 50%,

and (iii) if the DSCR as of such Payment Date is less than 1.15 to 1.00, then 100%; (b) if the production tracking rate for ABS IV

is less than 80%, then 100%, else 0%; and (c) if the LTV for ABS IV is greater than 65%, then 100%, else 0%. During the year

ended December 31, 2023, the Group made no excess cash flow payments on the ABS IV Notes.

ABS V Notes

In May 2022, the Group formed Diversified ABS V LLC (“ABS V”), a limited-purpose, bankruptcy-remote, wholly-owned

subsidiary, to issue BBB rated asset-backed securities for an aggregate principal amount of $445,000 at par. The ABS V Notes

are secured by a majority of the Group’s remaining upstream assets in Appalachia that were not securitized by previous

ABS transactions.

The ABS V Notes accrue interest at a stated 5.78% rate per annum and have a final maturity date of May 2039 with an

amortizing maturity of December 2030. Interest and principal payments on the ABS V Notes are payable on a monthly basis.

During the year ended December 31, 2023 and 2022, the Group incurred $19,332 and $14,319 in interest related to the ABS V

Notes, respectively. The fair value of the ABS V Notes is approximately $274,061 as of December 31, 2023.

Based on whether certain performance metrics are achieved, ABS V is required to apply 50% to 100% of any excess cash flow

to make additional principal payments. In particular, (a) (i) if the DSCR as of any payment date is greater than or equal to 1.25

to 1.00, then 0%, (ii) if the DSCR as of such payment date is less than 1.25 to 1.00 but greater than or equal to 1.15 to 1.00, then

50%, and (iii) if the DSCR as of such payment date is less than 1.15 to 1.00, then 100%; (b) if the production tracking rate for

ABS V is less than 80%, then 100%, else 0%; and (c) if the LTV for ABS V is greater than 65%, then 100%, else 0%. During the

year ended December 31, 2023, the Group made no excess cash flow payments on the ABS V Notes.

ABS VI Notes

In October 2022, the Group formed Diversified ABS VI LLC (“ABS VI”), a limited-purpose, bankruptcy-remote, wholly-owned

subsidiary, to issue, jointly with Oaktree, BBB+ rated asset-backed securities for an aggregate principal amount of $460,000

($235,750 to the Group, before fees, representative of its 51.25% ownership interest in the collateral assets). The ABS VI Notes

were issued at a 2.63% discount and are secured primarily by the upstream assets that were jointly acquired with Oaktree in

218	Diversified Energy Company plc Annual Report and Form 20-F2023

the Tapstone acquisition. The Group recorded its proportionate share of the note in its Consolidated Statement of

Financial Position.

The ABS VI Notes accrue interest at a stated 7.50% rate per annum and have a final maturity date of November 2039 with an

amortizing maturity of October 2031. Interest and principal payments on the ABS VI Notes are payable on a monthly basis.

During the year ended December 31, 2023 and 2022, the Group incurred $15,433 and $3,300 in interest related to the ABS VI

Notes, respectively. The fair value of the ABS VI Notes is approximately $158,284 as of December 31, 2023.

Based on whether certain performance metrics are achieved, ABS VI is required to apply 50% to 100% of any excess cash flow

to make additional principal payments. In particular, (a) (i) If the DSCR as of the applicable Payment Date is less than 1.15 to

1.00, then 100%, (ii) if the DSCR as of such Payment Date is greater than or equal to 1.15 to 1.00 and less than 1.25 to 1.00, then

50%, or (iii) if the DSCR as of such Payment Date is greater than or equal to 1.25 to 1.00, then 0%; (b) if the production tracking

rate for ABS VI is less than 80%, then 100%, else 0%; and (c) if the LTV for ABS VI is greater than 75%, then 100%, else 0%.

During the year ended December 31, 2023, the Group made no excess cash flow payments on the ABS VI Notes.

ABS VII Notes

In November 2023, the Group formed DP Lion Equity Holdco LLC, a limited-purpose, bankruptcy-remote, wholly-owned

subsidiary, to issue Class A and Class B asset-backed securities (collectively “ABS VII”) which are secured by certain upstream

producing assets in Appalachia. The Class A Notes are rated BBB+ and were issued for an aggregate principal amount of

$142,000. The Class B Notes are rated BB- and were issued for an aggregate principal amount of $20,000.

The ABS VII Class A Notes accrue interest at a stated 8.243% rate per annum and have a final maturity date of November 2043

with an amortizing maturity of February 2034. The ABS VII Class B Notes accrue interest at a stated 12.725% rate per annum

and have a final maturity date of November 2043 with an amortizing maturity of August 2032. Interest and principal payments

on the ABS VII Class A and Class B Notes are payable on a monthly basis.

In December 2023, the Group divested 80% of the equity ownership in DP Lion Equity Holdco LLC to outside investors,

generating cash proceeds of $30,000. The Group evaluated the remaining 20% interest in DP Lion Equity Holdco LLC and

determined that the governance structure is such that the Group does not have the ability to exercise control, joint control, or

significant influence over the DP Lion Equity Holdco LLC entity. Accordingly, this entity is not consolidated within the Group’s

financial statements for the year ended December 31, 2023. The Group’s remaining investment in the LLC of $7,500 is

accounted for at fair value in accordance with IFRS 9, Financial Instruments (“IFRS 9”).

Refer to Note 5 for additional information regarding the DP Lion Equity Holdco LLC equity sale.

Debt Covenants - ABS I, II, III, IV, V AND VI NOTES (Collectively, The “ABS Notes”) and

Term Loan I

The ABS Notes and Term Loan I are subject to a series of covenants and restrictions customary for transactions of this type,

including (i) that the Issuer maintains specified reserve accounts to be used to make required interest payments in respect of

the ABS Notes and Term Loan I, (ii) provisions relating to optional and mandatory prepayments and the related payment of

specified amounts, including specified make-whole payments in the case of the ABS Notes and Term Loan I under certain

circumstances, (iii) certain indemnification payments in the event, among other things, that the assets pledged as collateral for

the ABS Notes and Term Loan I are used in stated ways defective or ineffective, (iv) covenants related to recordkeeping,

access to information and similar matters, and (v) the Issuer will comply with all laws and regulations which it is subject to

including ERISA, Environmental Laws, and the USA Patriot Act (ABS III-V only).

The ABS Notes and Term Loan I are also subject to customary accelerated amortization events provided for in the indenture,

including events tied to failure to maintain stated debt service coverage ratios, failure to maintain certain production metrics,

certain change of control and management termination events, and the failure to repay or refinance the ABS Notes and Term

Loan I on the applicable scheduled maturity date.

The ABS Notes and Term Loan I are subject to certain customary events of default, including events relating to non-payment

of required interest, principal, or other amounts due on or with respect to the ABS Notes and Term Loan I, failure to comply

with covenants within certain time frames, certain bankruptcy events, breaches of specified representations and warranties,

failure of security interests to be effective and certain judgments.

As of December 31, 2023 the Group was in compliance with all financial covenants for the ABS Notes, Term Loan I and the

Credit Facility.

Sustainability-Linked Borrowings

CREDIT FACILITY

The Credit Facility contains three sustainability-linked performance targets (“SPTs”) which, depending on the Group’s

performance thereof, may result in adjustments to the applicable margin with respect to borrowings thereunder:

—GHG Emissions Intensity: The Group’s consolidated Scope 1 emissions and Scope 2 emissions, each measured as MT CO2e

per MMcfe;

—Asset Retirement Performance: The number of wells the Group successfully retires during any fiscal year; and

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	219

—TRIR Performance: The arithmetic average of the two preceding fiscal years and current period total recordable injury rate

computed as the Total Number of Recordable Cases (as defined by the Occupational Safety and Health Administration)

multiplied by 200,000 and then divided by total hours worked by all employees during any fiscal year.

The goals set by the Credit Facility for each of these categories are aspirational and represent higher thresholds than the

Group has publicly set for itself. The economic repercussions of achieving or failing to achieve these thresholds, however, are

relatively minor, ranging from subtracting five basis points to adding five basis points to the applicable margin level in any

given fiscal year.

An independent third-party assurance provider is required to certify the Group’s performance of the SPTs.

ABS III & IV

In connection with the issuance of the ABS III & IV notes, the Group retained an independent international provider of

sustainability research and services to provide and maintain a “sustainability score” with respect to Diversified Energy

Company PLC and to the extent such score is below a minimum threshold established at the time of issue of the ABS III & IV

notes, the interest payable with respect to the subsequent interest accrual period will increase by five basis points. This score

is not dependent on the Group meeting or exceeding any sustainability performance metrics but rather an overall assessment

of the Group’s corporate sustainability profile. Further, this score is not dependent on the use of proceeds of the ABS III & IV

notes and there were no such restrictions on the use of proceeds other than pursuant to the terms of the Group’s Credit

Facility. The Group informs the ABS III & IV note holders in monthly note holder statements as to any change in interest rate

payable on the ABS III & IV notes as a result of the change in this sustainability score.

ABS V & VI

In addition, a “second party opinion provider” certified the terms of the ABS V & VI notes as being aligned with the framework

for sustainability-linked bonds of the International Capital Markets Association (“ICMA”), applicable to bond instruments for

which the financial and/or structural characteristics vary depending on whether predefined sustainability objectives, or SPTs,

are achieved. The framework has five key components (1) the selection of key performance indicators (“KPIs”), (2) the

calibration of SPTs, (3) variation of bond characteristics depending on whether the KPIs meet the SPTs, (4) regular reporting

of the status of the KPIs and whether SPTs have been met and (5) independent verification of SPT performance by an external

reviewer such as an auditor or environmental consultant. Unlike the ICMA’s framework for green bonds, its framework for

sustainability-linked bonds does not require a specific use of proceeds.

The ABS V & VI notes contain two SPTs. The Group must achieve, and have certified by April 28, 2027 for ABS V and May 28,

2027 for ABS VI (1) a reduction in Scope 1 and Scope 2 GHG emissions intensity to 2.85 MT CO2e/MMcfe, and/or (2) a

reduction in Scope 1 methane emissions intensity to 1.12 MT CO2e/MMcfe. For each of these SPTs that the Group fails to meet,

or have certified by an external verifier that it has met, by April 28, 2027 for ABS V and May 28, 2027 for ABS VI, the interest

rate payable with respect to the ABS V & VI notes will be increased by 25 basis points. In each case, an independent third-

party assurance provider will be required to certify the Group’s performance of the above SPTs by the applicable deadlines.

COMPLIANCE

As of December 31, 2023, the Group met or was in compliance with all sustainability-linked debt metrics.

Future Maturities

The following table provides a reconciliation of the Group’s future maturities of its total borrowings as of the reporting date

as follows:

	December 31, 2023	December 31, 2022
Not later than one year	$200,822	$271,096
Later than one year and not later than five years	864,264	778,887
Later than five years	259,762	448,183
Total borrowings	$1,324,848	$1,498,166

Finance Costs

The following table represents the Group’s finance costs for each of the periods presented:

	Year Ended
	December 31, 2023	December 31, 2022	December 31, 2021
Interest expense, net of capitalized and income amounts(a)	$117,808	$86,840	$42,370
Amortization of discount and deferred finance costs	16,358	13,903	8,191
Other	—	56	67
Total finance costs	$134,166	$100,799	$50,628

(a)Includes payments related to borrowings and leases.

220	Diversified Energy Company plc Annual Report and Form 20-F2023

Financing Activities

Reconciliation of borrowings arising from financing activities:

	Year Ended
	December 31, 2023	December 31, 2022	December 31, 2021
Balance at beginning of period	$1,440,329	$1,010,355	$717,240
Acquired as part of a business combination	—	2,437	3,801
Sale of equity interest	(154,966)	—	—
Proceeds from borrowings	1,537,230	2,587,554	1,727,745
Repayments of borrowings	(1,547,912)	(2,139,686)	(1,436,367)
Costs incurred to secure financing	(13,776)	(34,234)	(10,255)
Amortization of discount and deferred financing costs	16,358	13,903	8,191
Cash paid for interest	(116,784)	(83,958)	(42,673)
Finance costs and other	116,148	83,958	42,673
Balance at end of period	$1,276,627	$1,440,329	$1,010,355

NOTE 22 - TRADE AND OTHER PAYABLES

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

The following table includes a detail of trade and other payables. The fair value approximates the carrying value as of the

periods presented:

	December 31, 2023	December 31, 2022
Trade payables	$49,487	$90,437
Other payables	4,003	3,327
Total trade and other payables	$53,490	$93,764

Trade and other payables are unsecured, non-interest bearing and paid as they become due.

NOTE 23 - OTHER LIABILITIES

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

The following table includes details of other liabilities as of the periods presented:

	December 31, 2023	December 31, 2022
Other non-current liabilities
Other non-current liabilities	$2,224	$5,375
Total other non-current liabilities	$2,224	$5,375
Other current liabilities
Accrued expenses(a)	$99,723	$140,058
Net revenue clearing(b)	79,056	186,244
Asset retirement obligations - current	5,402	4,529
Revenue to be distributed(c)	93,322	90,899
Total other current liabilities	$277,503	$421,730

(a)As of December 31, 2023 accrued expenses decreased primarily due to a $50,541 decrease in hedge settlements payables, resulting from

lower commodity prices throughout 2023. As of December 31, 2022 accrued expenses primarily consisted of $61,896 for hedge settlements

payables, $21,372 for accrued post production expense, $15,127 in accrued payroll and bonus and $10,832 for accrued lease operating

expense. The remaining balance consisted of accrued capital projects and operating expenses. Refer to the Financial Review for more

information on year-over-year changes in other liabilities and their fixed and variable nature.

(b)Net revenue clearing is estimated revenue that is payable to third-party working interest owners. The year-over-year decrease, similar to

commodity receivables, was a result of lower commodity prices year-over-year.

(c)Revenue to be distributed is revenue that is payable to third-party working interest owners, but has yet to be paid due to title, legal,

ownership or other issues. The Group releases the underlying liability as the aforementioned issues become resolved. As the timing of

resolution is unknown, the Group records the balance as a current liability. Revenue to be distributed increased year-over-year as a result of

the Group’s growth.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	221

NOTE 24 - FAIR VALUE AND FINANCIAL INSTRUMENTS

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

Fair Value

The fair value of an asset or liability is the price that would be received to sell that asset or paid to transfer that liability in an

orderly transaction occurring in the principal market (or most advantageous market in the absence of a principal market) for

such asset or liability. In estimating fair value, the Group utilizes valuation techniques that are consistent with the market

approach, the income approach and/or the cost approach. Such valuation techniques are consistently applied. Inputs to

valuation techniques include the assumptions that market participants would use in pricing an asset or liability. IFRS 13, Fair

Value Measurement (“IFRS 13”) establishes a fair value hierarchy for valuation inputs that gives the highest priority to quoted

prices in active markets for identical assets or liabilities and the lowest priority to unobservable inputs. The fair value hierarchy

is defined as follows:

Level 1:	Inputs are unadjusted, quoted prices in active markets for identical assets at the measurement date.
Level 2:	Inputs (other than quoted prices included in Level 1) can include the following:

(1)Observable prices in active markets for similar assets;

(2)Prices for identical assets in markets that are not active;

(3)Directly observable market inputs for substantially the full term of the asset; and

(4)Market inputs that are not directly observable but are derived from or corroborated by observable

market data.

Level 3:	Unobservable inputs which reflect the Directors’ best estimates of what market participants would use in pricing<br><br>the asset at the measurement date.

Financial Instruments

WORKING CAPITAL

The carrying values of cash and cash equivalents, trade receivables, other current assets, accounts payable and other current

liabilities in the Consolidated Statement of Financial Position approximate fair value because of their short-term nature. For

trade receivables, the Group applies the simplified approach permitted by IFRS 9, Financial Instruments (“IFRS 9”), which

requires expected lifetime losses to be recognized from initial recognition of the receivables. Financial liabilities are initially

measured at fair value and subsequently measured at amortized cost.

For borrowings, derivative financial instruments, and leases the following methods and assumptions were used to estimate

fair value:

BORROWINGS

The fair values of the Group’s ABS Notes and Term Loan I are considered to be a Level 2 measurement on the fair value

hierarchy. The carrying values of the borrowings under the Group’s Credit Facility (to the extent utilized) approximates fair

value because the interest rate is variable and reflective of market rates. The Group considers the fair value of its Credit

Facility to be a Level 2 measurement on the fair value hierarchy.

LEASES

The Group initially measures the lease liability at the present value of the future lease payments. The lease payments are

discounted using the interest rate implicit in the lease. When this rate cannot be readily determined, the Group uses its

incremental borrowing rate.

DERIVATIVE FINANCIAL INSTRUMENTS

The Group measures the fair value of its derivative financial instruments based upon a pricing model that utilizes market-based

inputs, including, but not limited to, the contractual price of the underlying position, current market prices, natural gas and

liquids forward curves, discount rates such as the U.S. Treasury yields, SOFR curve, and volatility factors.

The Group has classified its derivative financial instruments into the fair value hierarchy depending upon the data utilized to

determine their fair values. The Group’s fixed price swaps (Level 2) are estimated using third-party discounted cash flow

calculations using the NYMEX futures index for natural gas and oil derivatives and OPIS for NGLs derivatives. The Group

utilizes discounted cash flow models for valuing its interest rate derivatives (Level 2). The net derivative values attributable to

the Group’s interest rate derivative contracts as of December 31, 2023 are based on (i) the contracted notional amounts, (ii)

active market-quoted SOFR yield curves and (iii) the applicable credit-adjusted risk-free rate yield curve.

The Group’s call options, put options, collars and swaptions (Level 2) are valued using the Black-Scholes model, an industry

standard option valuation model that takes into account inputs such as contract terms, including maturity, and market

parameters, including assumptions of the NYMEX and OPIS futures index, interest rates, volatility and credit worthiness. Inputs

to the Black-Scholes model, including the volatility input are obtained from a third-party pricing source, with independent

verification of the most significant inputs on a monthly basis. A change in volatility would result in a change in fair value

measurement, respectively.

The Group’s basis swaps (Level 2) are estimated using third-party calculations based upon forward commodity price curves.

222	Diversified Energy Company plc Annual Report and Form 20-F2023

CONTINGENT CONSIDERATION

These liabilities represent the estimated fair value of potential future payments the Group may be required to remit under the

terms of historical purchase agreements entered into for asset acquisitions and business combinations. In instances when the

contingent consideration relates to the acquisition of a group of assets, the Group records changes in the fair value of the

contingent consideration through the basis of the asset acquired rather than through other income (expense) in

the Consolidated Statement of Comprehensive Income as it does for business combinations. During the years ended

December 31, 2023, 2022 and 2021, the Group recorded $0, $1,036 and $9,482, respectively, in revaluations related to

contingent consideration associated with asset acquisitions and $0, $0 and $8,963, respectively, associated with

business combinations.

The contingent consideration represented in the Group’s financial statements is associated with the 2020 Carbon and EQT

acquisitions. The maximum contingent consideration payment of $15,000 associated with the Carbon acquisition and the

remaining contingent consideration payment of $8,547 associated with the EQT acquisition was made during the year ended

December 31, 2022, settling both contingencies in their entirety.

The Group remeasures the fair value of the contingent consideration at each reporting period. This estimate requires

assumptions to be made, including forecasting the NYMEX Henry Hub natural gas settlement prices relative to stated floor and

target prices in future periods. In determining the fair value of the contingent consideration liability, the Group used the Monte

Carlo simulation model, which considers unobservable input variables, representing a Level 3 measurement. While valued

under this technique, presently there are no remaining contingent payments.

There were no transfers between fair value levels for the year ended December 31, 2023.

The following table includes the Group's financial instruments as of the periods presented:

	December 31, 2023	December 31, 2022
Cash and cash equivalents	$3,753	$7,329
Trade receivables and accrued income	190,207	296,781
Other non-current assets	9,172	4,351
Other non-current liabilities(a)	(1,946)	(1,669)
Other current liabilities(b)	(272,101)	(417,201)
Derivative financial instruments at fair value	(557,460)	(1,429,966)
Leases	(31,122)	(28,862)
Borrowings	(1,324,848)	(1,498,166)
Total	$(1,984,345)	$(3,067,403)

(a)Excludes the long-term portion of the value associated with the upfront promote received from Oaktree.

(b)Includes accrued expenses, net revenue clearing and revenue to be distributed. Excludes taxes payable and asset retirement obligations.

NOTE 25 - FINANCIAL RISK MANAGEMENT

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

The Group is exposed to a variety of financial risks such as market risk, credit risk, liquidity risk, capital risk and collateral risk.

The Group manages these risks by monitoring the unpredictability of financial markets and seeking to minimize potential

adverse effects on its financial performance on a continuous basis.

The Group’s principal financial liabilities are comprised of borrowings, leases and trade and other payables, used primarily to

finance and financially guarantee its operations. The Group’s principal financial assets include cash and cash equivalents and

trade and other receivables derived from its operations.

The Group also enters into derivative financial instruments which, depending on market dynamics, are recorded as assets or

liabilities. To assist with the design and composition of its hedging program, the Group engages a specialist firm with the

appropriate skills and experience to manage its risk management derivative-related activities.

Market Risk

Market risk is the possibility that the fair value of future cash flows of a financial instrument will fluctuate due to changes in

market prices. Market risk is comprised of two types of risk: interest rate risk and commodity price risk. Financial instruments

affected by market risk include borrowings and derivative financial instruments. Derivative and non-derivative financial

instruments are used to manage market price risks resulting from changes in commodity prices and foreign exchange rates,

which could have a negative effect on assets, liabilities or future expected cash flows.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	223

INTEREST RATE RISK

The Group is subject to market risk exposure related to changes in interest rates. The Group’s borrowings primarily consist of

fixed-rate amortizing notes and its variable rate Credit Facility as illustrated below.

	December 31, 2023		December 31, 2022
	Borrowings	Interest Rate(a)	Borrowings	Interest Rate(a)
ABS Notes and Term Loan I	$1,158,221	5.67%	$1,435,082	5.70%
Credit Facility	$159,000	8.66%	$56,000	7.42%

(a)The interest rate on the ABS Notes and Term Loan I borrowings represents the weighted average fixed-rate of the notes while the interest

rate presented for the Credit Facility represents the floating rate as of December 31, 2023 and 2022, respectively. During the year ended

December 31, 2022, the Credit Facility transitioned from LIBOR to SOFR during the regular redetermination in late Spring 2022. The Group

did not experience a material impact from the transition.

Refer to Note 21 for additional information regarding the ABS Notes, Term Loan I and Credit Facility. The table below

represents the impact of a 100 basis point adjustment in the borrowing rate for the Credit Facility and the corresponding

impact on finance costs. This represents a reasonably possible change in interest rate risk.

Credit Facility Interest Rate Sensitivity	December 31, 2023	December 31, 2022
+100 Basis Points	$1,590	$560
-100 Basis Points	$(1,590)	$(560)

The Group strives to maintain a prudent balance of floating and fixed-rate borrowing exposure, particularly during uncertain

market conditions. As part of the Group’s risk mitigation strategy from time to time the Group enters into swap arrangements

to increase or decrease exposure to floating or fixed- interest rates to account for changes in the composition of borrowings in

its portfolio. As a result, the total principal hedged through the use of derivative financial instruments varies from period to

period. The fair value of the Group’s interest rate swaps represents a liability of $315 and $3,228 as of December 31, 2023 and

2022, respectively. Refer to Note 13 for additional information regarding derivative financial instruments.

COMMODITY PRICE RISK

The Group’s revenues are primarily derived from the sale of its natural gas, NGLs and oil production, and as such, the Group is

subject to commodity price risk. Commodity prices for natural gas, NGLs and oil can be volatile and can experience

fluctuations as a result of relatively small changes in supply, weather conditions, economic conditions and government actions.

For the years ended December 31, 2023, 2022 and 2021, the Group’s commodity revenue was $802,399, $1,873,011 and

$973,107, respectively. The Group enters into derivative financial instruments to mitigate the risk of fluctuations in commodity

prices. The total volumes hedged through the use of derivative financial instruments varies from period to period, but generally

the Group’s objective is to hedge at least 65% for the next 12 months, at least 50% in months 13 to 24, and a minimum of 30%

in months 25 to 36, of its anticipated production volumes. Refer to Note 13 for additional information regarding derivative

financial instruments.

By removing price volatility from a significant portion of the Group’s expected production through 2032, it has mitigated, but

not eliminated, the potential effects of changing prices on its operating cash flow for those periods. While mitigating negative

effects of falling commodity prices, these derivative contracts also limit the benefits the Group would receive from increases in

commodity prices.

Credit and Counterparty Risk

The Group is exposed to credit and counterparty risk from the sale of its natural gas, NGLs and oil. Trade receivables from

customers are amounts due for the purchase of natural gas, NGLs and oil. Collectability is dependent on the financial condition

of each customer. The Group reviews the financial condition of customers prior to extending credit and generally does not

require collateral in support of their trade receivables. The Group had no customers that comprised over 10% of its total trade

receivables from customers as of December 31, 2023 and 2022. As of December 31, 2023 and 2022, the Group’s trade

receivables from customers, net of the applicable allowance for credit losses, were $168,913 and $278,030, respectively.

The Group is also exposed to credit risk from joint interest owners, entities that own a working interest in the properties

operated by the Group. Joint interest receivables are classified in trade receivables, net in the Consolidated Statement of

Financial Position. The Group has the ability to withhold future revenue payments to recover any non-payment of joint interest

receivables. As of December 31, 2023 and 2022, the Group’s joint interest receivables, net of the applicable allowance for

credit losses, were $21,294 and $18,751, respectively.

Trade receivables are current and the Group believes these net receivables are collectible. Refer to Note 3 for

additional information.

224	Diversified Energy Company plc Annual Report and Form 20-F2023

Liquidity Risk

Liquidity risk is the possibility that the Group will not be able to meet its financial obligations as they fall due. The Group

manages this risk by maintaining adequate cash reserves through the use of cash from operations and borrowing capacity on

the Credit Facility. The Group also continuously monitors its forecast and actual cash flows to ensure it maintains an

appropriate amount of liquidity. The amounts disclosed in the following table are the contractual cash flows.

	Not Later Than<br><br>One Year	Later Than<br><br>One Year and<br><br>Not Later Than<br><br>Five Years	Later Than<br><br>Five Years
				Total
For the year ended December 31, 2023
Trade and other payables	$53,490	$—	$—	$53,490
Borrowings	200,822	864,264	259,762	1,324,848
Leases	12,358	22,531	—	34,889
Other liabilities(a)	178,779	2,224	—	181,003
Total	$445,449	$889,019	$259,762	$1,594,230
For the year ended December 31, 2022
Trade and other payables	$93,764	$—	$—	$93,764
Borrowings	271,096	778,887	448,183	1,498,166
Leases	10,925	21,523	—	32,448
Other liabilities(a)	326,302	5,375	—	331,677
Total	$702,087	$805,785	$448,183	$1,956,055

(a)Represents accrued expenses and net revenue clearing. Excludes taxes payable, asset retirement obligations and revenue to be distributed.

Capital Risk

The Group defines capital as the total of equity shareholders’ funds and long-term borrowings net of available cash balances.

The Group’s objectives when managing capital are to provide returns for shareholders, maintain appropriate leverage and

safeguard the ability to continue as a going concern while pursuing opportunities for growth through identifying and

evaluating potential acquisitions and constructing new infrastructure on existing proved leaseholds. The Directors do not

establish a quantitative return on capital criteria, but rather promote year-over-year adjusted EBITDA growth. The Group seeks

to maintain a leverage target at or under 2.5x.

Collateral Risk

As of December 31, 2023, the Group has pledged 100% of its upstream natural gas and oil properties in the Appalachia and

Central Region, along with certain midstream assets, to fulfill the collateral requirements for borrowings under the ABS Notes,

Term Loan I and Credit Facility. The fair value of the collateral is based on a third-party engineering reserve calculation using

estimated cash flows discounted at 10% and a commodities futures price schedule. Refer to Notes 5 and 21 for additional

information regarding acquisitions and borrowings, respectively.

NOTE 26 - COMMITMENTS AND CONTINGENCIES

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

Delivery Commitments

We have contractually agreed to deliver firm quantities of natural gas to various customers, which we expect to fulfill with

production from existing reserves. We regularly monitor our proved developed reserves to ensure sufficient availability to

meet these commitments. The following table summarizes our total gross commitments, compiled using best estimates based

on our sales strategy, as of December 31, 2023.

	Natural gas (MMcf)
2024	70,769
2025	16,658
2026	—
Thereafter	360,114

Litigation and Regulatory Proceedings

The Group is involved in various pending legal issues that have arisen in the ordinary course of business. The Group accrues for

litigation, claims and proceedings when a liability is both probable and the amount can be reasonably estimated. As of

December 31, 2023 and 2022, the Group did not have any material amounts accrued related to litigation or regulatory matters.

For any matters not accrued for, it is not possible to estimate the amount of any additional loss, or range of loss that is

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	225

reasonably possible, but, based on the nature of the claims, management believes that current litigation, claims and

proceedings are not, individually or in aggregate, after considering insurance coverage and indemnification, likely to have a

material adverse impact on the Group’s financial position, results of operations or cash flows.

The Group has no other contingent liabilities that would have a material impact on the Group’s financial position, results of

operations or cash flows.

Environmental Matters

The Group’s operations are subject to environmental regulation in all the jurisdictions in which it operates, and it was in

compliance as of December 31, 2023 and 2022. The Group is unable to predict the effect of additional environmental laws and

regulations which may be adopted in the future, including whether any such laws or regulations would adversely affect its

operations. The Group can offer no assurance regarding the significance or cost of compliance associated with any such new

environmental legislation once implemented.

NOTE 27 - RELATED PARTY TRANSACTIONS

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

The Group had no related party activity in 2023, 2022 or 2021.

NOTE 28 - SUBSEQUENT EVENTS

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

The Group determined the need to disclose the following material transactions that occurred subsequent to December 31,

2023, which have been described within each relevant footnote as follows:

Description	Footnote
Acquisitions and Divestitures	Note 5
Dividends	Note 18
226	Diversified Energy Company plc Annual Report and Form 20-F2023
---	---

SUPPLEMENTAL NATURAL GAS AND

OIL INFORMATION (UNAUDITED)

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND PER UNIT DATA)

Estimated Reserves

The process of estimating quantities of “proved” and “proved developed” reserves is very complex, requiring significant

subjective decisions in the evaluation of all available geological, engineering and economic data for each reservoir. The data

for a given reservoir may also change substantially over time as a result of numerous factors including, but not limited to,

additional development activity, evolving production history and continual reassessment of the viability of production under

varying economic conditions. As a result, revisions to existing reserve estimates may occur from time to time. Although every

reasonable effort is made to ensure that reserve estimates reported represent the most accurate assessments possible, the

subjective decisions and variances in available data for various reservoirs make these estimates generally less precise than

other estimates included in the financial statement disclosures.

For each of the years ended December 31, 2023, 2022 and 2021 in the table below, the estimated proved reserves were

independently evaluated by our independent engineers, NSAI, in accordance with petroleum engineering and evaluation

standards published by the Society of Petroleum Evaluation Engineers and definitions and guidelines established by the SEC.

Accordingly, the following reserve estimates are based upon existing economic and operating conditions. Reserve estimates

are inherently imprecise, and the Group’s reserve estimates are generally based upon extrapolation of historical production

trends, historical prices of natural gas and oil, and analogy to similar properties and volumetric calculations. Accordingly, the

Group’s estimates are expected to change, and such changes could be material and occur in the near term as future

information becomes available.

The following table summarizes the changes in the Group’s net proved reserves for the periods presented, all of which were

located in the U.S.:

	Natural Gas	NGLs	Oil	Total
	(MMcf)	(MBbls)	(MBbls)	(MMcfe)
December 31, 2020	2,860,792	60,206	4,760	3,250,588
Revisions of previous estimates(a)	498,927	4,045	3,052	541,509
Extensions, discoveries and other additions	—	—	—	—
Production	(234,643)	(3,558)	(592)	(259,543)
Purchase of reserves in place(b)	1,019,944	32,698	7,397	1,260,514
Sales of reserves in place(c)	(135,983)	(4,311)	(365)	(164,039)
December 31, 2021	4,009,037	89,080	14,252	4,629,029
Revisions of previous estimates(a)	306,696	11,694	492	379,812
Extensions, discoveries and other additions	13,098	1	37	13,326
Production	(255,597)	(5,200)	(1,554)	(296,121)
Purchase of reserves in place(b)	281,345	6,356	1,927	331,043
Sales of reserves in place(c)	(4,968)	—	(324)	(6,912)
December 31, 2022	4,349,611	101,931	14,830	5,050,177
Revisions of previous estimates(a)	(658,917)	153	(230)	(659,379)
Extensions, discoveries and other additions	712	—	50	1,012
Production	(256,378)	(5,832)	(1,377)	(299,632)
Purchase of reserves in place(b)	105,713	2,592	923	126,803
Sales of reserves in place(c)	(340,697)	(3,143)	(1,580)	(369,035)
December 31, 2023	3,200,044	95,701	12,616	3,849,946

(a)During 2023, commodity market pricing decreased significantly driving a net downward revision of 659,379 MMcfe. During 2022, commodity

market pricing was volatile and increased significantly due to the war between Russia and Ukraine as well as other geopolitical factors. These

factors primarily drove a net upward revision of 386,064 MMcfe due to changes in pricing that impacted well economics. These increases

were then offset in part by a 6,252 MMcfe downward revision for changes in timing. During 2021, commodity market pricing began to

rebound from the COVID-19 pandemic lows driving a net upward revision of 541,509 MMcfe.

(b)During 2023, purchases of reserves in place were primarily related to the Tanos II acquisition. During 2022, purchases of reserves in place

were primarily related to the East Texas Assets and ConocoPhillips acquisitions. During 2021, purchases of reserves in place were primarily

related to the Indigo, Tanos, Blackbeard, and Tapstone acquisitions. Refer to Note 5 for additional information about acquisitions.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	227

(c)During 2023, 2022 and 2021, sales of reserves in place were primarily related to the divestitures of non-core assets. Refer to Note 5 for

additional information about divestitures.

	Natural Gas	NGLs	Oil	Total
	(MMcf)	(MBbls)	(MBbls)	(MMcfe)
Total proved reserves as of:
December 31, 2021	4,009,037	89,080	14,252	4,629,029
December 31, 2022	4,349,611	101,931	14,830	5,050,177
December 31, 2023	3,200,044	95,701	12,616	3,849,946
Total proved developed reserves as of:
December 31, 2021	4,008,160	89,071	13,823	4,625,524
December 31, 2022	4,340,779	101,931	14,830	5,041,345
December 31, 2023	3,184,499	94,391	12,380	3,825,125
Total proved undeveloped reserves as of:
December 31, 2021	877	9	429	3,505
December 31, 2022	8,832	—	—	8,832
December 31, 2023	15,545	1,310	236	24,821

Capitalized Costs Relating to Natural Gas and Oil Producing Activities

Capitalized costs relating to natural gas and oil producing activities and related accumulated depreciation, depletion and

amortization were as follows:

	December 31, 2023	December 31, 2022	December 31, 2021
Proved properties	$3,206,739	$3,062,463	$2,866,353
Unproved properties	—	—	—
Total capitalized costs	3,206,739	3,062,463	2,866,353
Less: Accumulated depreciation, depletion and amortization	(716,364)	(506,655)	(336,275)
Net capitalized costs	$2,490,375	$2,555,808	$2,530,078

Costs Incurred in Natural Gas and Oil Property Acquisition, Exploration and

Development Activities

Costs incurred in natural gas and oil property acquisition, exploration and development activities were as follows:

	December 31, 2023	December 31, 2022	December 31, 2021
Proved properties	$78,582	$260,817	$718,353
Unproved properties	—	—	—
Total property acquisition costs	78,582	260,817	718,353
Total exploration and development costs	10,923	19,670	1,464
Capitalized interest	—	—	—
Total costs	$89,505	$280,487	$719,817

Standardized Measure of Discounted Future Net Cash Flows

The following information has been developed based on natural gas and crude oil reserve and production volumes estimated

by the Group’s engineering staff. It can be used for some comparisons, but should not be the only method used to evaluate the

Group or its performance. Further, the information in the following table may not represent realistic assessments of future cash

flows, nor should the Standardized Measure of Discounted Future Net Cash Flows (the “Standardized Measure”) be viewed as

representative of the current value of the Group.

The Group believes that the following factors should be taken into account when reviewing the following information:

—Future costs and selling prices will differ from those required to be used in these calculations;

—Due to future market conditions and governmental regulations, actual rates of production in future years may vary

significantly from the rate of production assumed in the calculations;

—Selection of a 10% discount rate is arbitrary and may not be a reasonable measure of the relative risk that is part of realizing

future net natural gas and oil revenues; and

—Future net cash flows may be subject to different rates of income taxation.

228	Diversified Energy Company plc Annual Report and Form 20-F2023

Under the Standardised Measure, future cash inflows were estimated by using the 12-month average index price for the

respective commodity, calculated as the unweighted arithmetic average for the first day of the month price for each month

during the year. Prices used for standardised measure (adjusted for basis and quality differentials) were as follows:

	December 31, 2023	December 31, 2022	December 31, 2021
Natural gas (Mcf)	$2.49	$6.29	$3.26
NGLs (Bbls)	21.59	43.68	29.19
Oil (Bbls)	71.89	94.01	62.55

Future cash inflows were reduced by estimated future development and production costs based on year-end costs to arrive at

net cash flow before tax. Future income tax expense was computed by applying year-end statutory tax rates to future pretax

net cash flows, less the tax basis of the properties involved and utilization of available tax carryforwards related to natural gas

and oil operations. The applicable accounting standards require the use of a 10% discount rate.

Management does not solely use the following information when making investment and operating decisions. These decisions

are based on a number of factors, including estimates of proved reserves and varying price and cost assumptions considered

more representative of a range of anticipated economic conditions. The Standardised Measure is as follows:

	December 31, 2023	December 31, 2022	December 31, 2021
Future cash inflows	$10,900,742	$32,155,117	$16,283,927
Future production costs	(5,345,117)	(8,923,660)	(5,773,240)
Future development costs(a)	(1,937,293)	(1,902,297)	(1,818,190)
Future income tax expense	(653,216)	(5,001,823)	(1,644,625)
Future net cash flows	2,965,116	16,327,337	7,047,872
10% annual discount for estimated timing of cash flows	(1,219,580)	(9,584,237)	(3,714,781)
Standardized Measure	$1,745,536	$6,743,100	$3,333,091

(a)Includes $1,715,585, $1,698,105 and $1,615,461 in asset retirement costs for the years ended December 31, 2023, 2022 and 2021, respectively.

Future cash inflows were reduced by estimated future production and development costs based on year-end costs to

determine pre-tax cash inflows. Future income taxes were computed by applying the year-end statutory rate to the excess of

pre-tax cash inflows over the Group’s tax basis in the associated proved natural gas and oil properties after giving effect to

permanent differences and tax credits.

Changes in the Standardized Measure were as follows:

	December 31, 2023	December 31, 2022	December 31, 2021
Standardized Measure, beginning of year	$6,743,100	$3,333,091	$1,005,307
Sales and transfers of natural gas and oil produced, net of<br><br>production costs	(431,629)	(1,498,272)	(742,375)
Net changes in prices and production costs	(5,850,625)	5,137,373	2,411,163
Extensions, discoveries, and other additions, net of future<br><br>production and development costs	(13,682)	28,038	—
Acquisition of reserves in place	122,613	555,773	980,837
Divestiture of reserves in place	(377,097)	(8,303)	(145,434)
Revisions of previous quantity estimates	(1,224,544)	702,585	609,100
Net change in income taxes	1,688,208	(1,378,438)	(622,314)
Changes in estimated future development costs	—	22,085	(5,612)
Previously estimated development costs incurred during<br><br>the year	—	7,711	—
Changes in production rates (timing) and other	206,646	(562,245)	(266,273)
Accretion of discount	882,546	403,702	108,692
Standardized Measure, end of year	$1,745,536	$6,743,100	$3,333,091
Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	229
---	---	---	---	---

Additional

Information

231	Payments to Governments Report 2023 (Unaudited)
233	Alternative Performance Measures (Unaudited)
237	Officers and Professional Advisors
238	Shareholder Information
246	Glossary of Terms
253	Signatures
248	Exhibits
230	Diversified Energy Company plc Annual Report and Form 20-F2023
---	---

Payments to Governments Report

2023 (Unaudited)

(AMOUNTS IN THOUSANDS)

This report provides a consolidated overview of the

payments to governments made by the Group for the year

2023 as required under Disclosure and Transparency Rule

4.3A issued by the UK's Financial Conduct Authority ("DTR

4.3A") and in accordance with The Reports on Payments to

Governments Regulations 2014 (as amended in 2015) ("the

UK Regulations"). DTR 4.3A requires companies listed on a

stock exchange in the UK and operating in the extractive

industry to publicly disclose payments to governments in

the countries where they undertake exploration,

prospection, discovery, development and extraction of

natural gas and oil deposits or other materials.

Basis of Preparation

Under the UK Regulations, the Group prepares a disclosure

on payments made to governments for each financial year

in relation to relevant activities of both the Group and any

of its subsidiary undertakings included in the Group

Financial Statements.

ACTIVITIES WITHIN THE SCOPE OF THE

DISCLOSURE

Payments made to governments that relate to the Group’s

activities involving the exploration, development, and

production of natural gas and oil reserves (“extractive

activities”) are included in this disclosure. Payments made

to governments that relate to activities other than

extractive activities are not included in this disclosure as

they are not within the scope of extractive activities as

defined by the UK Regulations.

GOVERNMENT

“Government” includes any national, regional or local

authority of a country, and includes a department, agency

or entity that is a subsidiary of a government.

CASH BASIS

Payments are reported on a cash basis, meaning that they

are reported in the period in which they are paid, as

opposed to being reported on an accrual basis, meaning

that they are reported in the period in which the

liabilities arise.

PROJECT DEFINITION

The UK Regulations require payments to be reported by

project (as a sub category within a country). They define a

“project” as the operational activities which are governed

by a single contract, license, lease, concession or similar

legal agreement, and form the basis for payment liabilities

with a government. If these agreements are substantially

interconnected, then they can be treated as a single project.

Under the UK Regulations “substantially interconnected”

means forming a set of operationally and geographically

integrated contracts, licenses, leases or concessions or

related agreements with substantially similar terms that are

signed with a government, giving rise to payment liabilities.

The number of projects will depend on the contractual

arrangements within a country and not necessarily on the

scale of activities. Moreover, a project will only appear in

this disclosure where relevant payments occurred during

the year in relation to that project. The UK Regulations

acknowledge that for some payments it may not be

possible to attribute a payment to a single project and

therefore such payments may be reported at the country

level. Corporate income taxes, which are typically not levied

at a project level, are an example of this.

MATERIALITY LEVEL

For each payment type, total payments below £86 to a

government are excluded from this report.

EXCHANGE RATE

Payments made in currencies other than USD are translated

for this report based on the foreign exchange rate at the

relevant quarterly average rate.

PAYMENT TYPES

The UK Regulations define a “payment” as an amount paid

whether in money or in kind, for relevant activities where

the payment is of any one of the types listed below:

PRODUCTION ENTITLEMENTS

Under production-sharing agreements (“PSA”) the

production is shared between the host government and the

other parties to the PSA. The host government typically

receives its share or entitlement in kind rather than being

paid in cash. For the year ended December 31, 2023, DEC

had no reportable production entitlements to

a government.

TAXES

This report includes taxes levied on income, personnel,

production or profits withheld from dividends, royalties and

interest received by DEC. Taxes levied on consumption,

sales, procurement (contractor’s withholding taxes),

environmental, property, customs and excise are not

reportable under the UK Regulations.

ROYALTIES

Payments for the rights to extract natural gas and oil

resources, typically at a set percentage of revenue less any

deductions that may be taken, and may be paid in cash or

in kind (valued in the same way as production entitlement).

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	231

DIVIDENDS

Dividend payments other than dividends paid to a

government as a shareholder of an entity unless paid in lieu

of production entitlements or royalties. For the year ended

December 31, 2023, DEC had no reportable dividend

payments to a government.

BONUSES

Signature, discovery and production bonuses and other

bonuses payable under licenses or concession agreements

are included in this report. These are usually paid upon

signing an agreement or a contract, or when a commercial

discovery is declared, or production has commenced or

production has reached a milestone. For the year ended

December 31, 2023, DEC had no reportable bonus

payments to a government.

FEES

In preparing this report, DEC has included license fees,

rental fees, entry fees and all other payments that are paid

in consideration for new and existing licenses and or

concessions. Fees paid to governments for administrative

services are excluded.

INFRASTRUCTURE IMPROVEMENTS

Payments which relate to the construction of infrastructure

(road, bridge or rail) not substantially dedicated for the use

of extractive activities. Payments which are of a social

investment in nature, for example building of a school or

hospital, are excluded.

Payments Overview

The tables below show the relevant payments to

governments made by DEC in the year ended

December 31, 2023 shown by country and payment type.

Of the seven payment types required by the UK

Regulations, DEC did not pay any production entitlements,

dividends, bonuses, fees and or infrastructure

improvements therefore those categories are not shown.

SUMMARY OF PAYMENTS TO GOVERNMENTS

(AMOUNTS IN THOUSANDS)

Countries	Taxes	Royalties	Total
United Kingdom	$—	$—	$—
United States	88,665	4,022	92,687
Total	$88,665	$4,022	$92,687

UNITED KINGDOM

Governments	Taxes	Royalties	Total
Oil and Gas Authority	$—	$—	$—
HM Revenue and Customs	—	—	—
The Crown Estate Scotland	—	—	—
Total	$—	$—	$—

UNITED STATES

Governments	Taxes	Royalties	Total
Commonwealth of Pennsylvania	$3,100	$—	$3,100
Commonwealth of Virginia	1,180	—	1,180
Internal Revenue Service	14,639	—	14,639
Office of Natural Resources Revenue	—	2,238	2,238
State of Alabama	134	—	134
State of Kentucky	8,090	—	8,090
State of Louisiana	16,437	—	16,437
State of Ohio	2,363	—	2,363
State of Oklahoma	12,140	1,473	13,613
State of Tennessee	285	—	285
State of Texas	19,612	311	19,923
State of West Virginia	10,685	—	10,685
Total	$88,665	$4,022	$92,687
232	Diversified Energy Company PLC Annual Report and Form 20-F2023
---	---

Alternative Performance Measures

(Unaudited)

(AMOUNTS IN THOUSANDS, EXCEPT PER SHARE AND

PER UNIT DATA)

We use APMs to improve the comparability of information

between reporting periods and to more accurately evaluate

cash flows, either by adjusting for uncontrollable or

transactional factors that are not comparable period-over-

period, or by aggregating measures, to aid the users of this

Annual Report & Form 20-F in understanding the activity

taking place across the Group. APMs are used by the

Directors for planning and reporting and should not be

considered an IFRS replacement. The measures are also

used in discussions with the investment analyst community

and credit rating agencies.

Adjusted EBITDA

As used herein, EBITDA represents earnings before interest, taxes, depletion, depreciation and amortization. adjusted EBITDA

includes adjusting for items that are not comparable period-over-period, namely, accretion of asset retirement obligation,

other (income) expense, loss on joint and working interest owners receivable, (gain) loss on bargain purchases, (gain) loss on

fair value adjustments of unsettled financial instruments, (gain) loss on natural gas and oil property and equipment, costs

associated with acquisitions, other adjusting costs, non-cash equity compensation, (gain) loss on foreign currency hedge, net

(gain) loss on interest rate swaps and items of a similar nature.

Adjusted EBITDA should not be considered in isolation or as a substitute for operating profit or loss, net income or loss, or

cash flows provided by operating, investing and financing activities. However, we believe such measure is useful to an investor

in evaluating our financial performance because it (1) is widely used by investors in the natural gas and oil industry as an

indicator of underlying business performance; (2) helps investors to more meaningfully evaluate and compare the results of

our operations from period to period by removing the often-volatile revenue impact of changes in the fair value of derivative

instruments prior to settlement; (3) is used in the calculation of a key metric in one of our Credit Facility financial covenants;

and (4) is used by us as a performance measure in determining executive compensation. When evaluating this measure, we

believe investors also commonly find it useful to evaluate this metric as a percentage of our total revenue, inclusive of settled

hedges, producing what we refer to as our adjusted EBITDA margin.

	Year Ended
	December 31, 2023	December 31, 2022	December 31, 2021
Net income (loss)	$759,701	$(620,598)	$(325,206)
Finance costs	134,166	100,799	50,628
Accretion of asset retirement obligations	26,926	27,569	24,396
Other (income) expense	(385)	(269)	8,812
Income tax (benefit) expense	240,643	(178,904)	(225,694)
Depreciation, depletion and amortization	224,546	222,257	167,644
(Gain) loss on bargain purchases	—	(4,447)	(58,072)
(Gain) loss on fair value adjustments of unsettled financial<br><br>instruments	(905,695)	861,457	652,465
(Gain) loss on natural gas and oil properties and<br><br>equipment(a)	20	93	901
(Gain) loss on sale of equity interest	(18,440)	—	—
Unrealized (gain) loss on investment	(4,610)	—	—
Impairment of proved properties	41,616	—	—
Costs associated with acquisitions	16,775	15,545	27,743
Other adjusting costs(b)	17,794	69,967	10,371
Non-cash equity compensation	6,494	8,051	7,400
(Gain) loss on foreign currency hedge	521	—	1,227
(Gain) loss on interest rate swap	2,722	1,434	530
Total adjustments	$(216,907)	$1,123,552	$668,351
Adjusted EBITDA	$542,794	$502,954	$343,145

(a)Excludes $24.2 million and $2 million in proceeds received for leasehold sales during the years ended December 31, 2023 and 2022.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	233

(b)Other adjusting costs for the year ended December 31, 2023 were primarily associated with legal and professional fees related to the U.S.

listing, legal fees for certain litigation, and expenses associated with unused firm transportation agreements. Other adjusting costs for the

year ended December 31, 2022 primarily consisted of $28 million in contract terminations which may allow the Group to obtain more

favorable pricing in the future and $31 million in costs associated with deal breakage and/or sourcing costs for acquisitions.

Net Debt

As used herein, net debt represents total debt as recognized on the balance sheet less cash and restricted cash. Total debt

includes our borrowings under the Credit Facility and borrowings under or issuances of, as applicable, our subsidiaries’

securitization facilities. We believe net debt is a useful indicator of our leverage and capital structure.

Net Debt-to-Adjusted EBITDA

As used herein, net debt-to-adjusted EBITDA, or “leverage” or “leverage ratio,” is measured as net debt divided by adjusted

EBITDA. We believe that this metric is a key measure of our financial liquidity and flexibility and is used in the calculation of a

key metric in one of our Credit Facility financial covenants.

	As of
	December 31, 2023	December 31, 2022	December 31, 2021
Credit Facility	$159,000	$56,000	$570,600
ABS I Notes	100,898	125,864	155,266
ABS II Notes	125,922	147,458	169,320
ABS III Notes	274,710	319,856	—
ABS IV Notes	99,951	130,144	—
ABS V Notes	290,913	378,796	—
ABS VI Notes	159,357	212,446	—
Term Loan I	106,470	120,518	137,099
Other	7,627	7,084	9,380
Total debt	$1,324,848	$1,498,166	$1,041,665
LESS: Cash	3,753	7,329	12,558
LESS: Restricted cash	36,252	55,388	19,102
Net debt	$1,284,843	$1,435,449	$1,010,005
Adjusted EBITDA	$542,794	$502,954	$343,145
Pro forma adjusted EBITDA(a)	$549,258	$574,414	$490,978
Net debt-to-pro forma adjusted EBITDA(b)	2.3x	2.5x	2.1x

(a)Pro forma adjusted EBITDA includes adjustments for the year ended December 31, 2023 for the Tanos II Acquisition to pro forma its results

for the full twelve months of operations. Similar adjustments were made for the year ended December 31, 2022 for the East Texas Assets and

ConocoPhillips acquisitions.

(b)Does not include adjustments for working capital which are often customary in the market.

234	Diversified Energy Company PLC Annual Report and Form 20-F2023

Total Revenue, Inclusive of Settled Hedges

As used herein, total revenue, inclusive of settled hedges, includes the impact of derivatives settled in cash. We believe that

total revenue, inclusive of settled hedges is a useful because it enables investors to discern our realized revenue after adjusting

for the settlement of derivative contracts.

Adjusted EBITDA Margin

As used herein, adjusted EBITDA margin is measured as adjusted EBITDA, as a percentage of total revenue, inclusive of settled

hedges. adjusted EBITDA margin includes the direct operating cost and the portion of general and administrative cost it takes

to produce each Mcfe. This metric includes operating expense, employees, administrative costs and professional services and

recurring allowance for credit losses, which include fixed and variable costs components. We believe that adjusted EBITDA

margin is a useful measure of our profitability and efficiency as well as our earnings quality because it measures the Group on a

more comparable basis period-over-period, given we are often involved in transactions that are not comparable

between periods.

	Year Ended
	December 31, 2023	December 31, 2022	December 31, 2021
Total revenue	$868,263	$1,919,349	$1,007,561
Net gain (loss) on commodity derivative instruments(a)	178,064	(895,802)	(320,656)
Total revenue, inclusive of settled hedges	$1,046,327	$1,023,547	$686,905
Adjusted EBITDA	$542,794	$502,954	$343,145
Adjusted EBITDA margin	52%	49%	50%

(a)Net gain (loss) on commodity derivative settlements represents cash (paid) or received on commodity derivative contracts. This excludes

settlements on foreign currency and interest rate derivatives as well as the gain (loss) on fair value adjustments for unsettled financial

instruments for each of the periods presented.

Free Cash Flow

As used herein, free cash flow represents net cash provided by operating activities less expenditures on natural gas and oil

properties and equipment and cash paid for interest. We believe that free cash flow is a useful indicator of our ability to

generate cash that is available for activities other than capital expenditures. The Directors believe that free cash flow provides

investors with an important perspective on the cash available to service debt obligations, make strategic acquisitions and

investments and pay dividends.

	Year Ended
	December 31, 2023	December 31, 2022	December 31, 2021
Net cash provided by operating activities	$410,132	$387,764	$320,182
LESS: Expenditures on natural gas and oil properties and<br><br>equipment	(74,252)	(86,079)	(50,175)
LESS: Cash paid for interest	(116,784)	(83,958)	(42,673)
Free cash flow	$219,096	$217,727	$227,334

Adjusted Operating Cost per Mcfe

Adjusted operating cost per Mcfe is a metric that allows us to measure the direct operating cost and the portion of general

and administrative cost it takes to produce each Mcfe. This metric, similar to adjusted EBITDA margin, includes operating

expense employees, administrative costs and professional services and recurring allowance for credit losses, which include

fixed and variable cost components.

Employees, administrative costs and professional services

As used herein, employees, administrative costs and professional services represents total administrative expenses excluding

cost associated with acquisitions, other adjusting costs and non-cash expenses. We use employees, administrative costs and

professional services because this measure excludes items that affect the comparability of results or that are not indicative of

trends in the ongoing business.

	Year Ended
	December 31, 2023	December 31, 2022	December 31, 2021
Total production (MMcfe)	299,632	296,121	259,543
Total operating expense	$440,562	$445,893	$291,213
Employees, administrative costs and professional services	78,659	77,172	56,812
Recurring allowance for credit losses	8,478	—	(4,265)
Adjusted operating cost	$527,699	$523,065	$343,760
Adjusted operating cost per Mcfe	$1.76	$1.77	$1.32
Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	235
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PV-10

PV-10 is a non-IFRS measure because it excludes the effects of applicable income tax. The Directors believe that the

presentation of the non-IFRS financial measure of PV-10 provides useful information to investors because it is widely used by

professional analysts and sophisticated investors in evaluating natural gas and oil companies. PV-10 is not a measure of

financial or operating performance under IFRS. PV-10 should not be considered as an alternative to the standardized measure

as defined under IFRS. Refer to Supplemental Natural Gas and Oil Information for a reconciliation of PV-10 to the

standardized measure of discounted future net cash flows, its most directly comparable IFRS measure. PV-10 differs from the

standardized measure of discounted future net cash flows because it does not include the effects of income taxes. Neither

PV-10 nor the standardized measure represents an estimate of fair market value of our natural gas and oil properties.

	As of
	December 31, 2023	December 31, 2022	December 31, 2021
		SEC Pricing(a)
PV-10
Pre-tax (Non-GAAP)(b)	$2,139,690	$8,825,462	$4,037,016
PV of Taxes	(394,154)	(2,082,362)	(703,925)
Standardized Measure	$1,745,536	$6,743,100	$3,333,091

(a)Our estimated net proved reserves were determined using average first-day-of-the-month prices for the prior 12 months in accordance with

SEC guidance. For natural gas volumes, the average Henry Hub spot price of $2.64, $6.36 and $3.60 per MMBtu as of December 31, 2023,

2022 and 2021, respectively, was adjusted for gravity, quality, local conditions, gathering and transportation fees, and distance from market.

For NGLs and oil volumes, the average WTI price of $78.21, $94.14 and $66.55 per Bbl as of December 31, 2023, 2022 and 2021, respectively,

was similarly adjusted for gravity, quality, local conditions, gathering and transportation, fees and distance from market. All prices are held

constant throughout the lives of the properties.

(b)The PV-10 of our proved reserves as of December 31, 2023, 2022 and 2021 was prepared without giving effect to taxes or hedges. PV-10 is a

non-GAAP and non-IFRS financial measure and generally differs from Standardized Measure, the most directly comparable GAAP measure,

because it does not include the effects of income taxes on future net cash flows. We believe that the presentation of PV-10 is relevant and

useful to our investors as supplemental disclosure to the Standardized Measure because it presents the discounted future net cash flows

attributable to our reserves prior to taking into account future corporate income taxes and our current tax structure. While the Standardized

Measure is free cash dependent on the unique tax situation of each company, PV-10 is based on a pricing methodology and discount factors

that are consistent for all companies. Because of this, PV-10 can be used within the industry and by creditors and securities analysts to

evaluate estimated net cash flows from proved reserves on a more comparable basis. Investors should be cautioned that neither PV-10 nor

the Standardized Measure represents an estimate of the fair market value of our proved reserves.

236	Diversified Energy Company PLC Annual Report and Form 20-F2023

Officers and Professional Advisors

Directors	David E. Johnson (Non-Executive Chairman (Independent upon appointment))<br><br>Martin K. Thomas (Non-Executive Vice Chairman)<br><br>Rusty Hutson, Jr. (Chief Executive Officer)<br><br>David J. Turner, Jr. (Independent Non-Executive Director)<br><br>Sandra M. Stash (Independent Non-Executive Director)<br><br>Kathryn Z. Klaber (Independent Non-Executive Director)<br><br>Sylvia Kerrigan (Senior Independent Non-Executive Director)
Registered Number	09156132 (England and Wales)
Registered Office	4th floor Phoenix House<br><br>1 Station Hill<br><br>Reading, Berkshire, RG1 1NB<br><br>United Kingdom
Headquarters	1600 Corporate Drive<br><br>Birmingham, Alabama 35242<br><br>United States
Company Secretary	Apex Secretaries LLP<br><br>6th Floor 140 London Wall<br><br>London EC2V 5DN<br><br>United Kingdom
Independent Auditors,<br><br>United Kingdom	PricewaterhouseCoopers LLP<br><br>1 Embankment Place<br><br>London WC2N 6RH<br><br>United Kingdom
Independent Registered<br><br>Public Accounting Firm,<br><br>United States	PricewaterhouseCoopers LLP<br><br>569 Brookwood Village #851<br><br>Birmingham, AL 35209<br><br>United States
Legal Advisor,<br><br>United Kingdom	Latham & Watkins (London) LLP<br><br>99 Bishopsgate<br><br>London ECM2 3XF<br><br>United Kingdom
Legal Advisor,<br><br>United States	Benjamin Sullivan, Senior Executive Vice President and Chief Legal & Risk Officer<br><br>414 Summers Street<br><br>Charleston, WV 25301<br><br>United States
Competent Person	Netherland, Sewell & Associates, Inc.<br><br>2100 Ross Avenue, Suite 2200<br><br>Dallas, Texas 75201<br><br>United States
Share Registrar	ComputerShare Investor Services PLC<br><br>The Pavilions, Bridgewater Road<br><br>Bristol, BS13 8AE<br><br>United Kingdom
Brokers	Tennyson Securities<br><br>23rd Floor, 20 Fenchurch Street<br><br>London EC3M 3BY<br><br>United Kingdom<br><br>Stifel Nicolaus Europe Limited<br><br>150 Cheapside<br><br>London, EC2V 6ET<br><br>United Kingdom	Peel Hunt LLP<br><br>7th Floor, 100 Liverpool Street<br><br>London EC2M 2AT<br><br>United Kingdom
Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	237
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Shareholder Information

MATERIAL CONTRACTS

Our material contracts as of December 31, 2023 include:

—Participation Agreement, dated October 2, 2020, by and

between Diversified Production LLC and OCM Denali

Holdings, LLC.

—Letter Agreement, dated January 12, 2022, by and

between Diversified Production LLC and OCM Denali

Holdings, LLC.

—Amended, Restated and Consolidated Revolving Credit

Agreement, dated December 7, 2018, among Diversified

Gas & Oil Corporation, as borrower, KeyBank National

Association, as administrative agent and issuing bank,

Keybanc Capital Markets, as sole lead arranger and sole

book runner and the lenders party thereto. For a

description of this contract, see Liquidity and

Capital Resources.

—First Amendment to Amended, Restated and

Consolidated Revolving Credit Agreement, dated April

18, 2019, among Diversified Gas & Oil Corporation, as

borrower, KeyBank National Association, as

administrative agent, the guarantors party thereto and

the lenders party thereto. For a description of this

contract, see Liquidity and Capital Resources.

—Second Amendment to Amended, Restated and

Consolidated Revolving Credit Agreement, dated June

28, 2019, among Diversified Gas & Oil Corporation, as

borrower, KeyBank National Association, as

administrative agent, the guarantors party thereto and

the lenders party thereto. For a description of this

contract, see Liquidity and Capital Resources.

—Third Amendment to Amended, Restated and

Consolidated Revolving Credit Agreement, dated

November 13, 2019, among Diversified Gas & Oil

Corporation, as borrower, KeyBank National Association,

as administrative agent, the guarantors party thereto and

the lenders party thereto. For a description of this

contract, see Liquidity and Capital Resources.

—Fourth Amendment to Amended, Restated and

Consolidated Revolving Credit Agreement, dated

January 9, 2020, among Diversified Gas & Oil

Corporation, as borrower, KeyBank National Association,

as administrative agent, the guarantors party thereto and

the lenders party thereto. For a description of this

contract, see Liquidity and Capital Resources.

—Fifth Amendment to Amended, Restated and

Consolidated Revolving Credit Agreement, dated

January 22, 2020, among Diversified Gas & Oil

Corporation, as borrower, KeyBank National Association,

as administrative agent, the guarantors party thereto and

the lenders party thereto. For a description of this

contract, see Liquidity and Capital Resources.

—Sixth Amendment to Amended, Restated and

Consolidated Revolving Credit Agreement, dated March

24, 2020, among Diversified Gas & Oil Corporation, as

borrower, KeyBank National Association, as

administrative agent, the guarantors party thereto and

the lenders party thereto. For a description of this

contract, see Liquidity and Capital Resources.

—Seventh Amendment to Amended, Restated and

Consolidated Revolving Credit Agreement, dated May 21,

2020, among Diversified Gas & Oil Corporation, as

borrower, KeyBank National Association, as

administrative agent, the guarantors party thereto and

the lenders party thereto. For a description of this

contract, see Liquidity and Capital Resources.

—Eighth Amendment to Amended, Restated and

Consolidated Revolving Credit Agreement, dated June

26, 2020, among Diversified Gas & Oil Corporation, as

borrower, KeyBank National Association, as

administrative agent, the guarantors party thereto and

the lenders party thereto. For a description of this

contract, see Liquidity and Capital Resources.

—Ninth Amendment to Amended, Restated and

Consolidated Revolving Credit Agreement, dated

November 19, 2020, among Diversified Gas & Oil

238	Diversified Energy Company PLC Annual Report and Form 20-F2023

Corporation, as borrower, KeyBank National Association,

as administrative agent, the guarantors party thereto and

the lenders party thereto. For a description of this

contract, see Liquidity and Capital Resources.

—Tenth Amendment to Amended, Restated and

Consolidated Revolving Credit Agreement, dated April 6,

2021, among Diversified Gas & Oil Corporation, as

borrower, KeyBank National Association, as

administrative agent, the guarantors party thereto and

the lenders party thereto. For a description of this

contract, see Liquidity and Capital Resources.

—Eleventh Amendment to Amended, Restated and

Consolidated Revolving Credit Agreement, dated May 11,

2021, among Diversified Gas & Oil Corporation, as

borrower, KeyBank National Association, as

administrative agent, the guarantors party thereto and

the lenders party thereto. For a description of this

contract, see Liquidity and Capital Resources.

—Twelfth Amendment to Amended, Restated and

Consolidated Revolving Credit Agreement, dated August

17, 2021, among the Diversified Gas & Oil Corporation, as

borrower, KeyBank National Association, as

administrative agent, the guarantors party thereto and

the lenders party thereto. For a description of this

contract, see Liquidity and Capital Resources.

—Thirteenth Amendment to Amended, Restated and

Consolidated Revolving Credit Agreement, dated

December 7, 2021, among Diversified Gas & Oil

Corporation, as borrower, KeyBank National Association,

as administrative agent, the guarantors party thereto and

the lenders party thereto. For a description of this

contract, see Liquidity and Capital Resources.

—Fourteenth Amendment to Amended, Restated and

Consolidated Revolving Credit Agreement, dated

February 4, 2022, among Diversified Gas & Oil

Corporation, as borrower, KeyBank National Association,

as administrative agent, the guarantors party thereto and

the lenders party thereto. For a description of this

contract, see Liquidity and Capital Resources.

—Fifteenth Amendment to Amended, Restated and

Consolidated Revolving Credit Agreement, dated

February 22, 2022, among Diversified Gas & Oil

Corporation, as borrower, KeyBank National Association,

as administrative agent, the guarantors party thereto and

the lenders party thereto. For a description of this

contract, see Liquidity and Capital Resources.

—Sixteenth Amendment to Amended, Restated and

Consolidated Revolving Credit Agreement, dated May

27, 2022, among Diversified Gas & Oil Corporation, as

borrower, KeyBank National Association, as

administrative agent, the guarantors party thereto and

the lenders party thereto. For a description of this

contract, see Liquidity and Capital Resources.

—Amended and Restated Revolving Credit Agreement,

dated as of August 2, 2022 among DP RBL CO LLC, as

borrower, Diversified Gas & Oil Corporation, as existing

borrower, KeyBank National Association, as

administrative agent and issuing bank, Keybanc Capital

Markets, as sole lead arranger and sole book runner and

the lenders party thereto. For a description of this

contract, see Liquidity and Capital Resources.

—First Amendment to Amended and Restated Revolving

Credit Agreement, dated as of March 1, 2023 among DP

RBL CO LLC, as borrower, Diversified Gas & Oil

Corporation, as existing borrower, KeyBank National

Association, as administrative agent and issuing bank,

Keybanc Capital Markets, as sole lead arranger and sole

book runner and the lenders party thereto. For a

description of this contract, see Liquidity and

Capital Resources.

—Second Amendment to Amended and Restated

Revolving Credit Agreement, dated as of April 27, 2023

among DP RBL CO LLC, as borrower, Diversified Gas &

Oil Corporation, as existing borrower, KeyBank National

Association, as administrative agent and issuing bank,

Keybanc Capital Markets, as sole lead arranger and sole

book runner and the lenders party thereto. For a

description of this contract, see Liquidity and Capital

Resources.

—Credit Agreement, dated May 26, 2020, by and between

DP Bluegrass LLC (f.k.a Carbon West Virginia Company,

LLC), as borrower and Munich Re Reserve Risk

Financing, Inc., as lender, as amended. For a description

of this contract, see Liquidity and Capital Resources.

—Indenture, dated November 13, 2019, by and between

Diversified ABS LLC, as issuer, and UMB Bank, N.A., as

indenture trustee and securities intermediary. For a

description of this contract, see Liquidity and

Capital Resources.

—First Amendment to Indenture, dated February 13, 2020,

by and between Diversified ABS LLC, as issuer, and UMB

Bank, N.A., as indenture trustee. For a description of this

contract, see Liquidity and Capital Resources.

—Indenture, dated April 9, 2020, by and between

Diversified ABS Phase II LLC, as issuer, and UMB Bank,

N.A., as indenture trustee and securities intermediary.

For a description of this contract, see Liquidity and

Capital Resources.

—Indenture, dated February 4, 2022, among Diversified

ABS Phase III LLC, as issuer, the guarantors named

therein and UMB Bank, N.A., as indenture trustee and

securities intermediary. For a description of this contract,

see Liquidity and Capital Resources.

—Indenture, dated February 23, 2022, by and between

Diversified ABS Phase IV LLC, as issuer, and UMB Bank,

N.A., as indenture trustee and securities intermediary.

For a description of this contract, see Liquidity and

Capital Resources.

—Indenture, dated May 27, 2022, among Diversified ABS

Phase V LLC, as issuer, Diversified ABS V Upstream LLC,

as guarantor and UMB Bank, N.A., as indenture trustee

and securities intermediary. For a description of this

contract, see Liquidity and Capital Resources.

—Indenture, dated October 27, 2022, among Diversified

ABS Phase VI LLC, as issuer, Diversified ABS VI

Upstream LLC and Oaktree ABS VI Upstream LLC, as

guarantors and UMB Bank, N.A., as indenture trustee and

securities intermediary. For a description of this contract,

see Liquidity and Capital Resources.

—Indenture, dated November 30, 2023, by and between

DP Lion Holdco, as issuer and UMB Bank, N.A., as

indenture trustee and securities intermediary. For a

description of this contract, see Liquidity and

Capital Resources.

—Service Agreement, dated January 30, 2017, by and

between Diversified Gas & Oil PLC and Rusty Hutson

—Service Agreement, dated January 30, 2017, by and

between Diversified Gas & Oil PLC and Bradley Gray

—2017 Equity Incentive Plan, as amended.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	239

EXCHANGE CONTROLS

Other than certain economic sanctions which may be in

place from time to time, there are currently no UK laws,

decrees or regulations restricting the import or export of

capital or affecting the remittance of dividends or other

payment to holders of ordinary shares who are non-

residents of the United Kingdom. Similarly, other than

certain economic sanctions which may be in force from

time to time, there are no limitations relating only to

nonresidents of the United Kingdom under English law or

the Group’s articles of association on the right to be a

holder of, and to vote in respect of, the ordinary shares.

Other than certain economic sanctions which may be in

place from time to time, there are currently no UK laws,

decrees or regulations restricting the import or export of

capital or affecting the remittance of dividends or other

payment to holders of ordinary shares who are non-

residents of the United Kingdom. Similarly, other than

certain economic sanctions which may be in force from

time to time, there are no limitations relating only to

nonresidents of the United Kingdom under English law or

the Group’s articles of association on the right to be a

holder of, and to vote in respect of, the ordinary shares.

TAXATION

Material United Kingdom Tax Considerations

The following statements are of a general nature and do not

purport to be a complete analysis of all potential UK tax

consequences of acquiring, holding and disposing of the

ordinary shares. They are based on current UK tax law and

on the current published practice of His Majesty’s Revenue

and Customs (“HMRC”) (which may not be binding on

HMRC), as of the date of this Annual Report & Form 20-F,

all of which are subject to change, possibly with

retrospective effect. They are intended to address only

certain UK tax consequences for holders of ordinary shares

who are tax resident in (and only in) the United Kingdom,

and in the case of individuals, domiciled in (and only in) the

United Kingdom (except where expressly stated otherwise)

who are the absolute beneficial owners of the ordinary

shares and any dividends paid on them and who hold the

ordinary shares as investments (other than in an individual

savings account or a self-invested personal pension). They

do not address the UK tax consequences which may be

relevant to certain classes of shareholders such as traders,

brokers, dealers, banks, financial institutions, insurance

companies, investment companies, collective investment

schemes, tax-exempt organizations, trustees, persons

connected with the Group, persons holding their ordinary

shares as part of hedging or conversion transactions,

shareholders who have (or are deemed to have) acquired

their ordinary shares by virtue of an office or employment,

and shareholders who are or have been officers or

employees of the Group. The statements do not apply to

any shareholder who either directly or indirectly holds or

controls 10% or more of the Group’s share capital (or class

thereof), voting power or profits.

The following is intended only as a general guide and is not

intended to be, nor should it be considered to be, legal or

tax advice to any particular prospective subscriber for, or

purchaser of, any ordinary shares. Accordingly, prospective

subscribers for, or purchasers of, any ordinary shares who

are in any doubt as to their tax position regarding the

acquisition, ownership or disposition of any ordinary shares

or who are subject to tax in a jurisdiction other than the

United Kingdom should consult their own tax advisers.

UK taxation of dividends

Withholding tax

The Group will not be required to withhold UK tax at source

when paying dividends. The amount of any liability to UK

tax on dividends paid by the Group will depend on the

individual circumstances of a shareholder.

Income tax

An individual shareholder who is resident for tax purposes

in the United Kingdom may, depending on his or her

particular circumstances, be subject to UK tax on dividends

received from the Group. An individual shareholder who is

not resident for tax purposes in the United Kingdom should

not be chargeable to UK income tax on dividends received

from the Group unless he or she carries on (whether solely

or in partnership) any trade, profession or vocation in the

United Kingdom through a branch or agency to which the

ordinary shares are attributable. There are certain

exceptions for trading in the United Kingdom through

independent agents, such as some brokers and investment

managers.

All dividends received by a UK tax resident individual

holder of any ordinary shares from the Group or from other

sources will form part of the shareholder’s total income for

income tax purposes and will constitute the top slice of that

income. A nil rate of income tax will apply to the first

£1,000 (reducing to £500 from April 6, 2024) of taxable

dividend income received by the shareholder in a tax year.

Income within the nil rate band will be taken into account in

determining whether income in excess of the nil rate band

falls within the basic rate, higher rate or additional rate tax

bands. Where the dividend income is above the £1,000

dividend allowance, the first £1,000 of the dividend income

will be charged at the nil rate and any excess amount will

be taxed at 8.75% to the extent that the excess amount falls

within the basic rate tax band, 33.75% to the extent that the

excess amount falls within the higher rate tax band and

39.35% to the extent that the excess amount falls within the

additional rate tax band.

Corporation tax

Corporate shareholders which are resident for tax purposes

in the United Kingdom should not be subject to UK

corporation tax on any dividend received from the Group

so long as the dividends qualify for exemption

(as is likely) and certain conditions are met (including

anti-avoidance conditions). If the conditions for exemption

are not met or cease to be satisfied, or such a shareholder

elects for an otherwise exempt dividend to be taxable, the

shareholder will be subject to UK corporation tax on

dividends received from the Group, at the rate of

corporation tax applicable to that shareholder (the main

rate of UK corporation tax is currently 25%).

Corporate shareholders who are not resident in the United

Kingdom will not generally be subject to UK corporation tax

on dividends unless they are carrying on a trade, profession

or vocation in the United Kingdom through a permanent

establishment in connection with which the ordinary shares

are used, held, or acquired.

A shareholder who is resident outside the United Kingdom

may be subject to non-UK taxation on dividend income

under local law.

240	Diversified Energy Company PLC Annual Report and Form 20-F2023

UK taxation of chargeable gains

UK resident shareholders

A disposal or deemed disposal of ordinary shares by an

individual or corporate shareholder who is tax resident in

the United Kingdom may, depending on the shareholder’s

circumstances and subject to any available exemptions or

reliefs, give rise to a chargeable gain or allowable loss for

the purposes of UK taxation of chargeable gains.

Any chargeable gain (or allowable loss) will generally be

calculated by reference to the consideration received for

the disposal of the ordinary shares less the allowable cost

to the shareholder of acquiring any such ordinary shares.

The applicable tax rates for individual shareholders realizing

a gain on the disposal of ordinary shares is, broadly, 10% for

basic rate taxpayers and 20% for higher and additional rate

taxpayers. For corporate shareholders, corporation tax is

generally charged on chargeable gains at the rate

applicable to the relevant corporate shareholder.

Non-UK shareholders

Shareholders who are not resident in the United Kingdom

and, in the case of an individual shareholder, not

temporarily non-resident, should not be liable for UK tax on

capital gains realized on a sale or other disposal of ordinary

shares unless (i) such ordinary shares are used, held or

acquired for the purposes of a trade, profession or vocation

carried on in the United Kingdom through a branch or

agency or, in the case of a corporate shareholder, through a

permanent establishment or (ii) where certain conditions

are met, the Group derives 75% or more of its gross value

from UK land. Shareholders who are not resident in the

United Kingdom may be subject to non-UK taxation on any

gain under local law.

Generally, an individual shareholder who has ceased to be

resident in the United Kingdom for UK tax purposes for a

period of five years or less and who disposes of any

ordinary shares during that period may be liable on their

return to the United Kingdom to UK taxation on any capital

gain realized (subject to any available exemption or relief).

UK stamp duty (“stamp duty”) and UK stamp duty reserve

tax (“SDRT”)

The statements in this paragraph are intended as a general

guide to the current position relating to stamp duty and

SDRT and apply to any shareholder irrespective of their

place of tax residence. Certain categories of person,

including intermediaries, brokers, dealers and persons

connected with depositary receipt arrangements and

clearance services, may not be liable to stamp duty or

SDRT or may be liable at a higher rate or may, although not

primarily liable for the tax, be required to notify and

account for it under the UK Stamp Duty Reserve Tax

Regulations 1986. The discussion below does not consider

any potential change of law.

Issue of shares

As a general rule (and except in relation to depositary

receipt systems and clearance services (as to which see

below)), no stamp duty or SDRT is payable on the issue of

the ordinary shares.

Clearance systems and depositary receipt issuers

An unconditional agreement to issue or transfer ordinary

shares to, or to a nominee or agent for, a person whose

business is or includes the issue of depositary receipts or

the provision of clearance services will generally be subject

to SDRT (or, where the transfer is effected by a written

instrument, stamp duty) at a higher rate of 1.5% of the

amount or value of the consideration given for the transfer

unless, in the context of a clearance service, the clearance

service has made and maintained an election under section

97A of the UK Finance Act 1986, or a “section 97A

election.” It is understood that HMRC regards the facilities

of DTC as a clearance service for these purposes and we

are not aware of any section 97A election having been

made by DTC. However, HMRC clearance has been received

by the Group confirming that no stamp duty or SDRT is

payable on the transfer of legal title to the existing ordinary

shares into the DTC clearing system, to the extent required

in order to implement the U.S. Listing at the effective time.

Such HMRC clearance only applies to transfers into the DTC

clearing system made on the Initial Depositary Transfer

Date in order to implement the U.S. Listing (and transfers of

ordinary shares held by Restricted Shareholders which are

transferred to Computershare Trust Company N.A. (as

depositary for the holders of the Restricted Shares) on the

Initial Depositary Transfer Date), and not subsequent

transfers into the DTC clearing system (other than certain

transfers of ordinary shares held by Restricted Shareholders

on the Initial Depositary Transfer Date).

Transfer of shares and DIs

No SDRT should be required to be paid on a paperless

transfer of ordinary shares through the clearance service

facilities of DTC, provided that no section 97A election has

been made by DTC, and such ordinary shares are held

through DTC at the time of any agreement for

their transfer.

No stamp duty will in practice be payable on a written

instrument transferring an ordinary share provided that the

instrument of transfer is executed and remains at all times

outside the United Kingdom. Where these conditions are

not met, the transfer of, or agreement to transfer, an

ordinary share could, depending on the circumstances,

attract a charge to stamp duty at the rate of 0.5% of the

amount or value of the consideration. If it is necessary to

pay stamp duty, it may also be necessary to pay interest

and penalties.

The Group has received HMRC clearance confirming that

agreements to transfer DIs which represent ordinary shares

held within the DTC clearance system will not be subject

to SDRT.

Material United States Federal Income Tax Considerations

The following discussion is a summary of the material U.S.

federal income tax consequences to U.S. Holders and Non-

U.S. Holders (each, as defined below) of the purchase,

ownership and disposition of an ordinary share issued

pursuant to this listing, but does not purport to be a

complete analysis of all potential U.S. federal tax effects.

The effects of other U.S. federal tax laws, such as estate and

gift tax laws, and any applicable state, local, or non-U.S. tax

laws are not discussed herein. This discussion is based on

the Code, Treasury Regulations promulgated thereunder,

judicial decisions, and published rulings and administrative

pronouncements of the U.S. Internal Revenue Service (the

“IRS”), in each case in effect as of the date hereof. These

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	241

authorities may change or be subject to differing

interpretations. Any such change or differing interpretation

may be applied retroactively in a manner that could

adversely affect a holder of an ordinary share. We have not

sought and will not seek any rulings from the IRS regarding

the matters discussed below. There can be no assurance

that the IRS or a court will not take a contrary position to

that discussed below regarding the tax consequences of

the purchase, ownership and disposition of our

ordinary shares.

This discussion is limited to U.S. Holders and Non-U.S.

Holders that each hold an ordinary share as a “capital asset”

within the meaning of Section 1221 of the Code (generally,

property held for investment). This discussion does not

address all U.S. federal income tax consequences relevant

to a holder’s particular circumstances, including the impact

of the Medicare contribution tax on net investment income

and the alternative minimum tax. In addition, it does not

address consequences relevant to holders subject to special

rules, including, without limitation:

—U.S. expatriates and former citizens or long-term

residents of the United States;

—U.S. Holders (as defined below) whose functional

currency is not the U.S. dollar;

—persons holding an ordinary share as part of a hedge,

straddle or other risk reduction strategy or as part of a

conversion transaction or other integrated investment;

—banks, insurance companies, and other financial

institutions;

—brokers, dealers or traders in securities;

—“controlled foreign corporations,” passive foreign

investment companies,” and corporations that

accumulate earnings to avoid U.S. federal income tax;

—partnerships or other entities or arrangements treated as

partnerships for U.S. federal income tax purposes and

other pass-through entities (and investors therein);

—tax-exempt organizations or governmental

organizations;

—persons deemed to sell an ordinary share under the

constructive sale provisions of the Code;

—persons who hold or receive an ordinary share pursuant

to the exercise of any employee stock option or

otherwise as compensation;

—tax qualified retirement plans;

—“qualified foreign pension funds” as defined in Section

897(l)(2) of the Code and entities of all the interests of

which are held by qualified foreign pension funds; and

—persons subject to special tax accounting rules as a

result of any item of gross income with respect to the

ordinary shares being taken into account in an applicable

financial statement.

If an entity or arrangement treated as a partnership for U.S.

federal income tax purposes holds an ordinary share, the

tax treatment of a partner in the partnership will depend on

the status of the partner, the activities of the partnership

and certain determinations made at the partner level.

Accordingly, partnerships holding an ordinary share and the

partners in such partnerships should consult their tax

advisors regarding the U.S. federal income tax

consequences to them.

THIS DISCUSSION IS FOR INFORMATIONAL PURPOSES ONLY AND

IS NOT TAX ADVICE. PROSPECTIVE INVESTORS SHOULD CONSULT

THEIR TAX ADVISORS WITH RESPECT TO THE APPLICATION OF

THE U.S. FEDERAL TAX LAWS TO THEIR PARTICULAR SITUATIONS

AS WELL AS ANY TAX CONSEQUENCES OF THE PURCHASE,

OWNERSHIP AND DISPOSITION OF AN ORDINARY SHARE ARISING

UNDER THE U.S. FEDERAL ESTATE OR GIFT TAX LAWS OR UNDER

THE LAWS OF ANY STATE, LOCAL OR NON-U.S. TAXING

JURISDICTION OR UNDER ANY APPLICABLE INCOME TAX TREATY.

U.S. Tax Status of Diversified Energy

Pursuant to Section 7874 of the Code, we believe we are

and will continue to be treated as a U.S. corporation for all

purposes under the Code. Since we will be treated as a U.S.

corporation for all purposes under the Code, we will not be

treated as a “passive foreign investment company,” as such

rules apply only to non-U.S. corporations for U.S. federal

income tax purposes.

U.S. Holders

For purposes of this discussion, a “U.S. Holder” is any

beneficial owner of an ordinary share that, for U.S. federal

income tax purposes, is or is treated as any of the following:

—an individual who is a citizen or resident of the United

States;

—a corporation created or organized under the laws of the

United States, any state thereof, or the District of

Columbia;

—an estate, the income of which is subject to U.S. federal

income tax regardless of its source; or

242	Diversified Energy Company PLC Annual Report and Form 20-F2023

—a trust that (1) is subject to the primary supervision of a

U.S. court and the control of one or more “United States

persons” (within the meaning of Section 7701(a)(30) of

the Code), or (2) has a valid election in effect to be

treated as a United States person for U.S. federal income

tax purposes.

Distributions

Distributions, if any, made on the ordinary shares, generally

will be included in a U.S. Holder’s income as ordinary

dividend income to the extent of the Group’s current or

accumulated earnings and profits. Distributions in excess of

the Group’s current and accumulated earnings and profits

will be treated as a tax-free return of capital to the

extent of a U.S. Holder’s tax basis in the ordinary shares and

thereafter as capital gain from the sale or exchange of such

ordinary shares. Dividends received by a corporate U.S.

Holder may be eligible for a dividends-received deduction,

subject to applicable limitations. Dividends received by

certain non-corporate U.S. Holders (including individuals)

are generally taxed at the lower applicable long-term

capital gains rates, provided certain holding period and

other requirements are satisfied.

Sales, Certain Redemptions or Other Taxable Dispositions of

Ordinary Shares

Upon the sale, certain redemption or other taxable

disposition of an ordinary share, a U.S. Holder generally will

recognize gain or loss equal to the difference between the

amount realized and the U.S. Holder’s tax basis in the

ordinary shares. Any gain or loss recognized on a taxable

disposition of an ordinary share will be capital gain or loss.

Such capital gain or loss will be long-term capital gain or

loss if a U.S. Holder’s holding period at the time of the sale,

redemption or other taxable disposition of the ordinary

shares is longer than one year. Long-term capital gains

recognized by certain non-corporate U.S. Holders

(including individuals) are generally subject to a reduced

rate of U.S. federal income tax. The deductibility of capital

losses is subject to limitations.

Non-U.S. Holders

For purposes of this discussion, a “Non-U.S. Holder” is any

beneficial owner of an ordinary share that is neither a U.S.

Holder nor an entity or arrangement treated as a

partnership for U.S. federal income tax purposes.

Distributions

If the Group makes distributions of cash or property on the

ordinary shares, such distributions will constitute dividends

for U.S. federal income tax purposes to the extent paid from

the Group’s current or accumulated earnings and profits, as

determined under U.S. federal income tax principles.

Amounts not treated as dividends for U.S. federal income

tax purposes will constitute a return of capital and first be

applied against and reduce a Non-U.S. Holder’s adjusted tax

basis in its ordinary shares, but not below zero. Generally, a

distribution that constitutes a return of capital will be

subject to U.S. federal withholding tax at a rate of 15% if the

Non-U.S. Holders’ ordinary shares constitute a U.S. real

property interest (“USRPI”). However, we may elect to

withhold at a rate of up to 30% of the entire amount of the

distribution, even if the Non-U.S. Holders’ ordinary shares

do not constitute a USRPI. For additional information

regarding when a Non-U.S. Holder may treat its ownership

of the ordinary shares as not constituting a USRPI, refer to

the subsection below titled Sale or Other Taxable

Disposition. However, because a Non-U.S. Holder would not

have any U.S. federal income tax liability with respect to a

return of capital distribution, a Non-U.S. Holder would be

entitled to request a refund of any U.S. federal income tax

that is withheld from a return of capital distribution

(generally by timely filing a U.S. federal income tax return

for the taxable year in which the tax was withheld). Any

excess will be treated as capital gain and will be treated as

described below under the subsection titled Sale or Other

Taxable Disposition.

Subject to the discussion below on effectively connected

income, dividends paid to a Non-U.S. Holder of an ordinary

share will be subject to U.S. federal withholding tax at a rate

of 30% of the gross amount of the dividends (or such lower

rate specified by an applicable income tax treaty, provided

the Non-U.S. Holder furnishes a valid IRS Form W-8BEN or

W-8BEN-E (or other applicable documentation) certifying

qualification for the lower treaty rate). A Non-U.S. Holder

that does not timely furnish the required documentation,

but that qualifies for a reduced treaty rate, may obtain a

refund of any excess amounts withheld by timely filing an

appropriate claim for refund with the IRS. Non-U.S. Holders

should consult their tax advisors regarding their entitlement

to benefits under any applicable income tax treaty.

If dividends paid to a Non-U.S. Holder are effectively

connected with the Non-U.S. Holder’s conduct of a trade or

business within the United States (and, if required by an

applicable income tax treaty, the Non-U.S. Holder maintains

a permanent establishment in the United States to which

such dividends are attributable), the Non-U.S. Holder will be

exempt from the U.S. federal withholding tax described

above. To claim the exemption, the Non-U.S. Holder must

furnish to the applicable withholding agent a valid IRS Form

W-8ECI, certifying that the dividends are effectively

connected with the Non-U.S. Holder’s conduct of a trade or

business within the United States.

Any such effectively connected dividends will be subject to

U.S. federal income tax on a net income basis at the regular

rates. A Non-U.S. Holder that is a corporation also may be

subject to a branch profits tax at a rate of 30% (or such

lower rate specified by an applicable income tax treaty) on

such effectively connected dividends, as adjusted for

certain items. Non-U.S. Holders should consult their tax

advisors regarding any applicable tax treaties that may

provide for different rules.

Sale or Other Taxable Disposition

Subject to the discussion below on information reporting,

backup withholding and FATCA (as defined below), a Non-

U.S. Holder will not be subject to U.S. federal income tax on

any gain realized upon the sale or other taxable disposition

of an ordinary share unless:

—the gain is effectively connected with the Non-U.S.

Holder’s conduct of a trade or business within the United

States (and, if required by an applicable income tax

treaty, the Non-U.S. Holder maintains a permanent

establishment in the United States to which such gain is

attributable);

—the Non-U.S. Holder is a nonresident alien individual

present in the United States for 183 days or more during

the taxable year of the disposition and certain other

requirements are met; or

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	243

—our ordinary shares constitute a USRPI because we are

(or have been during the shorter of the five-year period

ending on the date of the disposition or the Non-U.S.

Holder’s holding period) a U.S. real property holding

corporation (“USRPHC”) for U.S. federal income tax

purposes.

Gain described in the first bullet point above generally will

be subject to U.S. federal income tax on a net income basis

at the regular rates. A Non-U.S. Holder that is a corporation

also may be subject to a branch profits tax at a rate of 30%

(or such lower rate specified by an applicable income tax

treaty) on such effectively connected gain, as adjusted for

certain items.

A Non-U.S. Holder described in the second bullet point

above will be subject to U.S. federal income tax at a rate of

30% (or such lower rate specified by an applicable income

tax treaty) on gain realized upon the sale or other taxable

disposition of our ordinary shares, which may be offset by

U.S. source capital losses of the Non-U.S. Holder (even

though the individual is not considered a resident of the

United States), provided the Non-U.S. Holder has timely

filed U.S. federal income tax returns with respect to

such losses.

With respect to the third bullet point above, due to the

nature of our assets and operations, the Group believes it is

(and will continue to be) a USRPHC under the Code and the

ordinary shares constitute (and we expect the ordinary

shares to continue to constitute) a USRPI. Non-U.S. Holders

generally are subject to a 15% withholding tax on the

amount realized from a sale or other taxable disposition of

a USRPI, such as the ordinary shares, which is required to

be collected from any sale or disposition proceeds.

Furthermore, such Non-U.S. Holders are subject to U.S.

federal income tax (at the regular rates) in respect of any

gain on their sale or disposition of the ordinary shares and

are required to file a U.S. tax return to report such gain and

pay any tax liability that is not satisfied by withholding. Any

gain should be determined in U.S. dollars, based on the

excess, if any, of the U.S. dollar value of the consideration

received over the Non-U.S. Holder’s basis in the ordinary

shares determined in U.S. dollars under the rules applicable

to Non-U.S. Holders. A Non-U.S. Holder may, by filing a U.S.

tax return, be able to claim a refund for any withholding tax

deducted in excess of the tax liability on any gain. However,

if the ordinary shares are considered “regularly traded on

an established securities market” (within the meaning of the

Treasury Regulations) then Non-U.S. Holders will not be

subject to the 15% withholding tax on the disposition of

their ordinary shares, even if such ordinary shares

constitute USRPIs. Moreover, if the ordinary shares are

considered “regularly traded on an established securities

market” (within the meaning of the Treasury Regulations)

and the Non-U.S. Holder actually or constructively owns or

owned, at all times during the shorter of the five-year

period ending on the date of the disposition or the Non-U.S.

Holder’s holding period, 5% or less of the ordinary shares

taking into account applicable constructive ownership rules,

such Non-U.S. Holder may treat its ownership of the

ordinary shares as not constituting a USRPI and will not be

subject to U.S. federal income tax on any gain realized upon

the sale or other taxable disposition of the ordinary shares

(in addition to not being subject to the 15% withholding tax

described above) or U.S. tax return filing requirements. The

Group expects the ordinary shares to be treated as

“regularly traded on an established securities market” so

long as the ordinary shares are listed on the NYSE and

regularly quoted by brokers or dealers making a market in

such ordinary shares.

Non-U.S. Holders should consult their tax advisors

regarding tax consequences of our treatment as a USRPHC

and regarding potentially applicable income tax treaties

that may provide for different rules.

Information Reporting and Backup Withholding

U.S. Holders

Information reporting requirements generally will apply to

payments of distributions on the ordinary shares and the

proceeds of a sale of an ordinary share paid to a U.S. Holder

unless the U.S. Holder is an exempt recipient and, if

requested, certifies as to that status. Backup withholding

generally will apply to those payments if the U.S. Holder

fails to provide an appropriate certification with its correct

taxpayer identification number or certification of exempt

status. Any amounts withheld under the backup

withholding rules will be allowed as a refund or credit

against a U.S. Holder’s U.S. federal income tax liability,

provided the required information is timely furnished to

the IRS.

Non-U.S. Holders

Payments of dividends on the ordinary shares will not be

subject to backup withholding, provided the applicable

withholding agent does not have actual knowledge or

reason to know the Non-U.S. Holder is a United States

person and the Non-U.S. Holder either certifies its non-U.S.

status, such as by furnishing a valid IRS Form W-8BEN,

W-8BEN-E, or W-8ECI, or otherwise establishes an

exemption. However, information returns are required to be

filed with the IRS in connection with any distributions on

our ordinary shares paid to the Non-U.S. Holder, regardless

of whether such distributions constitute dividends or

whether any tax was actually withheld. In addition,

proceeds of the sale or other taxable disposition of our

ordinary shares within the United States or conducted

through certain U.S.-related brokers generally will not be

subject to backup withholding or information reporting if

the applicable withholding agent receives the certification

described above and does not have actual knowledge or

reason to know that such holder is a United States person

or the holder otherwise establishes an exemption. Proceeds

of a disposition of our ordinary shares conducted through a

non-U.S. office of a non-U.S. broker generally will not be

subject to backup withholding or information reporting.

Copies of information returns that are filed with the IRS

may also be made available under the provisions of an

applicable treaty or agreement to the tax authorities of the

country in which the Non-U.S. Holder resides or

is established.

Backup withholding is not an additional tax. Any amounts

withheld under the backup withholding rules may be

allowed as a refund or a credit against a Non-U.S. Holder’s

U.S. federal income tax liability, provided the required

information is timely furnished to the IRS.

Additional Withholding Tax on Payments Made to

Foreign Accounts

Withholding taxes may be imposed under Sections 1471 to

1474 of the Code (such Sections commonly referred to as

the Foreign Account Tax Compliance Act, or “FATCA”) on

certain types of payments made to non-U.S. financial

institutions and certain other non-U.S. entities. Specifically,

244	Diversified Energy Company PLC Annual Report and Form 20-F2023

a 30% withholding tax may be imposed on dividends on, or

(subject to the proposed Treasury Regulations discussed

below) gross proceeds from the sale or other disposition of,

our ordinary shares paid to a “foreign financial institution”

or a “non-financial foreign entity” (each as defined in the

Code), unless (1) the foreign financial institution undertakes

certain diligence and reporting obligations, (2) the non-

financial foreign entity either certifies it does not have any

“substantial United States owners” (as defined in the Code)

or furnishes identifying information regarding each

substantial United States owner, or (3) the foreign financial

institution or non-financial foreign entity otherwise qualifies

for an exemption from these rules. If the payee is a foreign

financial institution and is subject to the diligence and

reporting requirements in (1) above, it must enter into an

agreement with the U.S. Department of the Treasury

requiring, among other things, that it undertake to identify

accounts held by certain “specified United States persons”

or “United States owned foreign entities” (each as defined

in the Code), annually report certain information about such

accounts, and withhold 30% on certain payments to non-

compliant foreign financial institutions and certain other

account holders. Foreign financial institutions located in

jurisdictions that have an intergovernmental agreement

with the United States governing FATCA may be subject to

different rules.

Under the applicable Treasury Regulations and

administrative guidance, withholding under FATCA

generally applies to payments of dividends on our ordinary

shares. While withholding under FATCA would have applied

also to payments of gross proceeds from the sale or other

disposition of stock, including our ordinary shares, on or

after January 1, 2019, proposed Treasury Regulations

eliminate FATCA withholding on payments of gross

proceeds entirely. Taxpayers generally may rely on these

proposed Treasury Regulations until final Treasury

Regulations are issued.

Prospective investors should consult their tax advisors

regarding the potential application of withholding under

FATCA to their investment in our ordinary shares.

DOCUMENTS ON DISPLAY

The SEC maintains an Internet site that contains reports,

proxy and information statements, and other information

regarding issuers that file electronically with the SEC. All of

the SEC filings made electronically by Diversified are

available to the public on the SEC website at www.sec.gov

(commission file number 001-41870).

We also make our electronic filings with the SEC available

at no cost on our Investor Relations website,

www.ir.div.energy, as soon as reasonably practicable after

we file such material with, or furnish it to, the SEC. Our

website address is www.div.energy. The information

contained on our website is not incorporated by reference

in this document.

CONTROLS AND PROCEDURES

This Annual Report & Form 20-F does not include a report

of management’s assessment regarding internal control

over financial reporting or an attestation report of the

Group’s registered public accounting firm due to a

transition period established by rules of the Securities and

Exchange Commission for newly public companies.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	245

Glossary of Terms

British pound sterling

U.S. dollar

ABS

Asset-Backed Security

Adjusted EBITDA

Adjusted EBITDA is an APM. Please

refer to the APM section in Additional

Information within this Annual Report

& Form 20-F for information on how

this metric is calculated and

reconciled to IFRS measures.

Adjusted EBITDA margin

Adjusted EBITDA margin is an APM.

Please refer to the APM section in

Additional Information within this

Annual Report & Form 20-F for

information on how this metric is

calculated and reconciled to IFRS

measures.

Adjusted operating cost

Adjusted operating cost is an APM.

Please refer to the APM section in

Additional Information within this

Annual Report & Form 20-F for

information on how this metric is

calculated and reconciled to

IFRS measures.

Adjusted operating cost per Mcfe

is an APM. Please refer to the APM

section in Additional Information

within this Annual Report & Form 20-

F for information on how this metric

is calculated and reconciled to

IFRS measures.

AIM

Alternative Investment Market

APM

Alternative Performance Measure

Bbl

Barrel or barrels of oil or natural

gas liquids

Bcfe

Billions of cubic fee equivalent

Board or BOD

Board of Directors

Boe

Barrel of oil equivalent, determined

by using the ratio of one Bbl of oil or

NGLs to six Mcf of natural gas. The

ratio of one barrel of oil or NGLs to

six Mcf of natural gas is commonly

used in the industry and represents

the approximate energy equivalence

of oil or NGLs to natural gas, and

does not represent the economic

equivalency of oil and NGLs to natural

gas. The sales price of a barrel of oil

or NGLs is considerably higher than

the sales price of six Mcf of

natural gas.

Boepd

Barrels of oil equivalent per day

Btu

A British thermal unit, which is a

measure of the amount of energy

required to raise the temperature

of one pound of water one

degree Fahrenheit.

CO2

Carbon dioxide

CO2e

Carbon dioxide equivalent

CEO

Chief Executive Officer

CFO

Chief Financial Officer

COO

Chief Operating Officer

DD&A

Depreciation, depletion

and amortization

E&P

Exploration and production

EBITDA

Earnings before interest, tax,

depreciation and amortization

EBITDAX

Earnings before interest, tax,

depreciation, amortization and

exploration expense

Employees, administrative costs and

professional services

Employees, administrative costs and

professional services is an APM.

Please refer to the APM section in

Additional Information within this

Annual Report & Form 20-F for

information on how this metric is

calculated and reconciled to

IFRS measures.

EPA

Environmental Protection Agency

EPS

Earnings per share

ERM

Enterprise Risk Management

ESG

Environmental, Social

and Governance

European Union

Free cash flow

Free cash flow is an APM. Please refer

to the APM section in Additional

Information within this Annual Report

& Form 20-F for information on how

this metric is calculated and

reconciled to IFRS measures.

FTSE

Financial Times Stock Exchange

G&A

General and administrative expense

GBP

British pound sterling

Henry Hub

A natural gas pipeline delivery point

that serves as the benchmark natural

gas price underlying NYMEX natural

gas futures contracts.

IAS

International Accounting Standard

IASB

International Accounting

Standards Board

IPO

Initial public offering

IFRS

International Financial

Reporting Standards

KWh

Kilowatt hour

LIBOR

London Inter-bank Offered Rate

LOE

Base lease operating expense is

defined as the sum of employee and

benefit expenses, well operating

246	Diversified Energy Company PLC Annual Report and Form 20-F2023

expense (net), automobile expense

and insurance cost.

LSE

London Stock Exchange

M&A

Mergers and acquisitions

Mbbls

Thousand barrels

Mboe

Thousand barrels of oil equivalent

Mboepd

Thousand barrels of oil equivalent

per day

Mcf

Thousand cubic feet of natural gas

Mcfe

Thousand cubic feet of natural

gas equivalent

Midstream

Midstream activities include the

processing, storing, transporting and

marketing of natural gas, NGLs

and oil.

Mmboe

Million barrels of oil equivalent

Mmbtu

Million British thermal units

Mmcf

Million cubic feet of natural gas

Mmcfe

Million cubic feet of natural

gas equivalent

Mont Belvieu

A mature trading hub with a high

level of liquidity and transparency

that sets spot and futures prices

for NGLs.

MT CO2e

Metric ton of carbon

dioxide equivalent

Motor Vehicle Accidents (“MVA”)

MVA is the rate of preventable

accidents per million miles driven.

Metric ton

Net debt

Net debt is an APM. Please refer to

the APM section in Additional

Information within this Annual Report

& Form 20-F for information on how

this metric is calculated and

reconciled to IFRS measures.

Net zero

Achieving an overall balance between

carbon emissions produced and

carbon emissions taken out of the

atmosphere, which includes making

changes to reduce emissions to the

lowest amount and offsetting as a

last resort. For Diversified net zero

means total Scope 1 and 2

GHG emissions.

NGLs

Natural gas liquids, such as ethane,

propane, butane and natural gasoline

that are extracted from natural gas

production streams.

NYMEX

New York Mercantile Exchange

Oil

Includes crude oil and condensate

PSU

Performance stock unit

PV-10

A calculation of the present value of

estimated future natural gas and oil

revenues, net of forecasted direct

expenses, and discounted at an

annual rate of 10%. This calculation

does not consider income taxes and

utilizes a pricing assumption

consistent with the forward curve at

December 31, 2023.

Realized price

The cash market price less all

expected quality, transportation and

demand adjustments.

RSU

Restricted stock unit

SAM

Smarter Asset Management

SOFR

Secured Overnight Financing Rate

TCFD

Task Force on Climate-Related

Financial Disclosures

Total Recordable Incident Rate

(“TRIR”)

TRIR is the number of work-related

injuries per 200,000 work hours.

Total revenue, inclusive of settled

hedges

Total revenue, inclusive of settled

hedges, is an APM. Please refer to the

APM section in Additional

Information within this Annual Report

& Form 20-F for information on how

this metric is calculated and

reconciled to IFRS measures.

TSR

Total Shareholder Return

TTM

Trailing twelve months

United Kingdom

U.S.

United States

USD

U.S. dollar

WTI

West Texas Intermediate grade crude

oil, used as a pricing benchmark for

sales contracts and NYMEX oil

futures contracts.

Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	247

Exhibits

The following documents are filed in the Securities and Exchange Commission (“SEC”) EDGAR system, as part of this Annual

Report on Form 20-F, and can be viewed on the SEC’s website.

Exhibit<br><br>No.			Incorporated by reference<br><br>(File No. 001-41870, unless<br><br>otherwise indicated)
		Description	Form	Exhibit	Filing Date
1.1	(c)	Articles of Association of the Registrant.	20FR12B	1.1	11/16/2023
1.2	(c)	Form of Amended and Restated Articles of Association of the Registrant.	20FR12B	1.2	11/16/2023
2.1	(c)	Form of Share Certificate upon listing on the New York Stock Exchange.	20FR12B	2.1	11/16/2023
4.1	(c)(f)	Participation Agreement, dated October 2, 2020, by and between<br><br>Diversified Production LLC and OCM Denali Holdings, LLC.	20FR12B	4.1	11/16/2023
4.2	(c)(f)	Letter Agreement, dated January 12, 2022, by and between Diversified<br><br>Production LLC and OCM Denali Holdings, LLC.	20FR12B	4.2	11/16/2023
4.3	(c)(f)	Amended, Restated and Consolidated Revolving Credit Agreement, dated<br><br>December 7, 2018, among Diversified Gas & Oil Corporation, as borrower,<br><br>KeyBank National Association, as administrative agent and issuing bank,<br><br>Keybanc Capital Markets, as sole lead arranger and sole book runner and the<br><br>lenders party thereto.	20FR12B	4.3	11/16/2023
4.4	(c)(f)	First Amendment to Amended, Restated and Consolidated Revolving Credit<br><br>Agreement, dated April 18, 2019, among Diversified Gas & Oil Corporation, as<br><br>borrower, KeyBank National Association, as administrative agent, the<br><br>guarantors party thereto and the lenders party thereto.	20FR12B	4.4	11/16/2023
4.5	(c)(f)	Second Amendment to Amended, Restated and Consolidated Revolving<br><br>Credit Agreement, dated June 28, 2019, among Diversified Gas & Oil<br><br>Corporation, as borrower, KeyBank National Association, as administrative<br><br>agent, the guarantors party thereto and the lenders party thereto.	20FR12B	4.5	11/16/2023
4.6	(c)(f)	Third Amendment to Amended, Restated and Consolidated Revolving Credit<br><br>Agreement, dated November 13, 2019, among Diversified Gas & Oil<br><br>Corporation, as borrower, KeyBank National Association, as administrative<br><br>agent, the guarantors party thereto and the lenders party thereto.	20FR12B	4.6	11/16/2023
4.7	(c)(f)	Fourth Amendment to Amended, Restated and Consolidated Revolving<br><br>Credit Agreement, dated January 9, 2020, among Diversified Gas & Oil<br><br>Corporation, as borrower, KeyBank National Association, as administrative<br><br>agent, the guarantors party thereto and the lenders party thereto.	20FR12B	4.7	11/16/2023
4.8	(c)(f)	Fifth Amendment to Amended, Restated and Consolidated Revolving Credit<br><br>Agreement, dated January 22, 2020, among Diversified Gas & Oil<br><br>Corporation, as borrower, KeyBank National Association, as administrative<br><br>agent, the guarantors party thereto and the lenders party thereto.	20FR12B	4.8	11/16/2023
4.9	(c)(f)	Sixth Amendment to Amended, Restated and Consolidated Revolving Credit<br><br>Agreement, dated March 24, 2020, among Diversified Gas & Oil Corporation,<br><br>as borrower, KeyBank National Association, as administrative agent, the<br><br>guarantors party thereto and the lenders party thereto.	20FR12B	4.9	11/16/2023
4.10	(c)(f)	Seventh Amendment to Amended, Restated and Consolidated Revolving<br><br>Credit Agreement, dated May 21, 2020, among Diversified Gas & Oil<br><br>Corporation, as borrower, KeyBank National Association, as administrative<br><br>agent, the guarantors party thereto and the lenders party thereto.	20FR12B	4.10	11/16/2023
4.11	(c)(f)	Eighth Amendment to Amended, Restated and Consolidated Revolving<br><br>Credit Agreement, dated June 26, 2020, among Diversified Gas & Oil<br><br>Corporation, as borrower, KeyBank National Association, as administrative<br><br>agent, the guarantors party thereto and the lenders party thereto.	20FR12B	4.11	11/16/2023
4.12	(c)(f)	Ninth Amendment to Amended, Restated and Consolidated Revolving<br><br>Credit Agreement, dated November 19, 2020, among Diversified Gas & Oil<br><br>Corporation, as borrower, KeyBank National Association, as administrative<br><br>agent, the guarantors party thereto and the lenders party thereto.	20FR12B	4.12	11/16/2023
4.13	(c)(f)	Tenth Amendment to Amended, Restated and Consolidated Revolving<br><br>Credit Agreement, dated April 6, 2021, among Diversified Gas & Oil<br><br>Corporation, as borrower, KeyBank National Association, as administrative<br><br>agent, the guarantors party thereto and the lenders party thereto.	20FR12B	4.13	11/16/2023
248	Diversified Energy Company PLC Annual Report and Form 20-F2023
---	---
Exhibit<br><br>No.			Incorporated by reference<br><br>(File No. 001-41870, unless<br><br>otherwise indicated)
---	---	---	---	---	---
		Description	Form	Exhibit	Filing Date
4.14	(c)(f)	Eleventh Amendment to Amended, Restated and Consolidated Revolving<br><br>Credit Agreement, dated May 11, 2021, among Diversified Gas & Oil<br><br>Corporation, as borrower, KeyBank National Association, as administrative<br><br>agent, the guarantors party thereto and the lenders party thereto.	20FR12B	4.14	11/16/2023
4.15	(c)(f)	Twelfth Amendment to Amended, Restated and Consolidated Revolving<br><br>Credit Agreement, dated August 17, 2021, among the Diversified Gas & Oil<br><br>Corporation, as borrower, KeyBank National Association, as administrative<br><br>agent, the guarantors party thereto and the lenders party thereto.	20FR12B	4.15	11/16/2023
4.16	(c)(f)	Thirteenth Amendment to Amended, Restated and Consolidated Revolving<br><br>Credit Agreement, dated December 7, 2021, among Diversified Gas & Oil<br><br>Corporation, as borrower, KeyBank National Association, as administrative<br><br>agent, the guarantors party thereto and the lenders party thereto.	20FR12B	4.16	11/16/2023
4.17	(c)(f)	Fourteenth Amendment to Amended, Restated and Consolidated Revolving<br><br>Credit Agreement, dated February 4, 2022, among Diversified Gas & Oil<br><br>Corporation, as borrower, KeyBank National Association, as administrative<br><br>agent, the guarantors party thereto and the lenders party thereto.	20FR12B	4.17	11/16/2023
4.18	(c)(f)	Fifteenth Amendment to Amended, Restated and Consolidated Revolving<br><br>Credit Agreement, dated February 22, 2022, among Diversified Gas & Oil<br><br>Corporation, as borrower, KeyBank National Association, as administrative<br><br>agent, the guarantors party thereto and the lenders party thereto.	20FR12B	4.18	11/16/2023
4.19	(c)(f)	Sixteenth Amendment to Amended, Restated and Consolidated Revolving<br><br>Credit Agreement, dated May 27, 2022, among Diversified Gas & Oil<br><br>Corporation, as borrower, KeyBank National Association, as administrative<br><br>agent, the guarantors party thereto and the lenders party thereto.	20FR12B	4.19	11/16/2023
4.20	(c)(f)	Amended and Restated Revolving Credit Agreement, dated as of August 2,<br><br>2022 among DP RBL CO LLC, as borrower, Diversified Gas & Oil<br><br>Corporation, as existing borrower, KeyBank National Association, as<br><br>administrative agent and issuing bank, Keybanc Capital Markets, as sole lead<br><br>arranger and sole book runner and the lenders party thereto.	20FR12B	4.20	11/16/2023
4.21	(c)(f)	First Amendment to Amended and Restated Revolving Credit Agreement,<br><br>dated March 1, 2023 among DP RBL CO LLC, as borrower, Diversified Gas &<br><br>Oil Corporation, as existing borrower, KeyBank National Association, as<br><br>administrative agent and issuing bank, Keybanc Capital Markets, as sole lead<br><br>arranger and sole book runner and the lenders party thereto.	20FR12B	4.21	11/16/2023
4.22	(c)(f)	Second Amendment to Amended and Restated Revolving Credit<br><br>Agreement, dated April 27, 2023 among DP RBL CO LLC, as borrower,<br><br>Diversified Gas & Oil Corporation, as existing borrower, KeyBank National<br><br>Association, as administrative agent and issuing bank, Keybanc Capital<br><br>Markets, as sole lead arranger and sole book runner and the lenders<br><br>party thereto.	20FR12B	4.22	11/16/2023
4.23	(c)(f)	Credit Agreement, dated May 26, 2020, by and between DP Bluegrass LLC<br><br>(f.k.a Carbon West Virginia Company, LLC), as borrower and Munich Re<br><br>Reserve Risk Financing, Inc., as lender, as amended.	20FR12B	4.23	11/16/2023
4.24	(c)(e)(f)	Indenture, dated November 13, 2019, by and between Diversified ABS LLC,<br><br>as issuer, and UMB Bank, N.A., as indenture trustee and<br><br>securities intermediary.	20FR12B	4.24	11/16/2023
4.25	(c)(e)(f)	First Amendment to Indenture, dated February 13, 2020, by and between<br><br>Diversified ABS LLC, as issuer, and UMB Bank, N.A., as indenture trustee.	20FR12B	4.25	11/16/2023
4.26	(c)(e)(f)	Indenture, dated April 9, 2020, by and between Diversified ABS Phase II<br><br>LLC, as issuer, and UMB Bank, N.A., as indenture trustee and<br><br>securities intermediary.	20FR12B	4.26	11/16/2023
4.27	(c)(e)(f)	Indenture, dated February 4, 2022, among Diversified ABS Phase III LLC, as<br><br>issuer, the guarantors named therein and UMB Bank, N.A., as indenture<br><br>trustee and securities intermediary.	20FR12B	4.27	11/16/2023
4.28	(c)(e)(f)	Indenture, dated February 23, 2022, by and between Diversified ABS Phase IV<br><br>LLC, as issuer, and UMB Bank, N.A., as indenture trustee and securities<br><br>intermediary.	20FR12B	4.28	11/16/2023
4.29	(c)(e)(f)	Indenture, dated May 27, 2022, among Diversified ABS Phase V LLC, as<br><br>issuer, Diversified ABS V Upstream LLC, as guarantor and UMB Bank, N.A.,<br><br>as indenture trustee and securities intermediary.	20FR12B	4.29	11/16/2023	Strategic Report	Corporate Governance	Group Financial Statements	Additional Information	249
---	---	---	---	---
Exhibit<br><br>No.			Incorporated by reference<br><br>(File No. 001-41870, unless<br><br>otherwise indicated)
---	---	---	---	---	---
		Description	Form	Exhibit	Filing Date
4.30	(c)(e)(f)	Indenture, dated October 27, 2022, among Diversified ABS Phase VI LLC, as<br><br>issuer, Diversified ABS VI Upstream LLC and Oaktree ABS VI Upstream LLC,<br><br>as guarantors and UMB Bank, N.A., as indenture trustee and securities<br><br>intermediary.	20FR12B	4.30	11/16/2023
4.31	(c)(e)(f)	Indenture, dated November 30, 2023, by and between DP Lion Holdco, as<br><br>issuer and UMB Bank, N.A., as indenture trustee and securities intermediary.	20FR12B	4.31	11/16/2023
4.32	(c)(d)	Service Agreement, dated January 30, 2017, by and between Diversified Gas<br><br>& Oil PLC and Rusty Hutson	20FR12B	4.32	11/16/2023
4.33	(c)(d)	Service Agreement, dated January 30, 2017, by and between Diversified Gas<br><br>& Oil PLC and Bradley Gray	20FR12B	4.33	11/16/2023
4.34	(c)	2017 Equity Incentive Plan, as amended.	20FR12B	4.34	11/16/2023
4.35	(c)	2023 Employee Stock Purchase Plan.	20FR12B	4.35	11/16/2023
8.1	(a)	Subsidiaries of the Registrant.
12.1	(a)	Certifications of the Chief Executive Officer and Chief Financial Officer<br><br>pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
13.1	(b)	Certifications of the Chief Executive Officer and Chief Financial Officer<br><br>pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
15.1	(a)	Consent of PricewaterhouseCoopers LLP.
15.2	(a)	Consent of Netherland, Sewell & Associates, Inc.
15.3	(a)	Netherland, Sewell & Associates, Inc. estimates of reserves and future<br><br>revenue to the Diversified Energy Company PLC (formerly known as<br><br>Diversified Gas & Oil PLC) interest in certain natural gas and oil properties<br><br>located in the United States as ofDecember 31, 2023.
99.1	(a)	Diversified Energy Company PLC US Clawback Policy Applicable to Executive<br><br>Officers
101		Inline XBRL data files.
104		Cover page inline interactive data file (formatted as Inline XBRL and contained<br><br>in Exhibit 101).

(a)Filed herewith.

(b)Furnished only.

(c)Previously filed.

(d)Management contract.

(e)Certain portions of this exhibit (indicated by “[***]”) have been redacted.

(f)Certain schedules and attachments have been omitted. The registrant hereby undertakes to provide further information regarding such

omitted materials to the Securities and Exchange Commission upon request.

250	Diversified Energy Company PLC Annual Report and Form 20-F2023

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LABUS_2022_Signature_B&W_V3.jpg

Signatures

The registrant hereby certifies that it meets all of the requirements for filing on Form 20-F and that it has duly caused and

authorized the undersigned to sign this annual report on its behalf.

Diversified Energy Company PLC

(Registrant)

/s/ Robert Russell (“Rusty”) Hutson, Jr.

Robert Russell (“Rusty”) Hutson, Jr.

Chief Executive Officer

March 19, 2024

Diversified Energy Company PLC

1600 Corporate Drive

Birmingham, Alabama,

35242 USA

www.div.energy

Document

Exhibit 8.1

Subsidiaries of Diversified Energy Company PLC as of December 31, 2023

Name of Subsidiary	Jurisdiction
Diversified Gas & Oil Corporation	United States
Diversified Production LLC	United States
Diversified Midstream LLC	United States
Diversified Energy Marketing, LLC	United States
Diversified ABS Holdings LLC	United States
Diversified ABS LLC	United States
Diversified ABS Phase II Holdings LLC	United States
Diversified ABS Phase II LLC	United States
Diversified ABS Phase III Holdings LLC	United States
Diversified ABS Phase III LLC	United States
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Document

Exhibit 12.1

Certification by the Chief Executive Officer

Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

I, Rusty Hutson, Jr., certify that:

1.I have reviewed this Annual Report on Form 20-F of Diversified Energy Company PLC;

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 registrant as of, and for, the periods presented in this report;

4.The registrant’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)) [omitted] for the registrant 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 registrant, 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)[omitted];

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’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 registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the company’s auditors and the audit committee of the registrant’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 registrant’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 registrant’s internal control over financial reporting.

March 19, 2024	/s/ Rusty Hutson, Jr.
Date	Rusty Hutson, Jr.
	Chief Executive Officer

Exhibit 12.1

Certification of the Chief Financial Officer

Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002

I, Bradley G. Gray, certify that:

1.I have reviewed this Annual Report on Form 20-F of Diversified Energy Company PLC;

(b)[omitted];

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

March 19, 2024	/s/ Bradley G. Gray
Date	Bradley G. Gray
	Chief Financial Officer

Document

Exhibit 13.1

Certification Pursuant to 18 U. S. C. Section 1350(b), as

Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, Rusty Hutson, Jr., the Chief Executive Officer, and Bradley G. Gray, the Chief Financial Officer of Diversified Energy Company PLC (the Company), hereby certify, that, to their knowledge:

1.The Annual Report on Form 20-F for the year ended December 31, 2023 (the Report), as filed with the Securities and Exchange Commission on March 19, 2024, fully complies with the requirements of Section 13(a) or Section 15(d) of the Securities Exchange Act of 1934, as amended; and

2.The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

March 19, 2024	/s/ Rusty Hutson, Jr.
Date	Rusty Hutson, Jr.
	Chief Executive Officer
March 19, 2024	/s/ Bradley G. Gray
Date	Bradley G. Gray
	Chief Financial Officer

Document

Exhibit 15.1

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

We hereby consent to the incorporation by reference in the Registration Statement on Form S-8 (No. 333-276139) of Diversified Energy Company Plc of our report dated March 19, 2024 relating to the financial statements, which appears in this Form 20-F.

/s/ PricewaterhouseCoopers LLP

Birmingham, Alabama

March 19, 2024.

Document

Exhibit 15.2

CONSENT OF INDEPENDENT PETROLEUM ENGINEERS AND GEOLOGISTS

We hereby consent to the inclusion in or incorporation by reference into the Annual Report on Form 20-F of Diversified Energy Company PLC (the "Annual Report") of our report prepared for Diversified Energy Company PLC dated March 4, 2024, with respect to estimates of proved reserves and future revenue to the Diversified Energy Company PLC interest, as of December 31, 2023, in certain oil and gas properties located in the Appalachian Basin and the Louisiana-Oklahoma-Texas Area of the United States. We also consent to all references to our firm, including the reference to us under the heading "Officers and Professional Advisors", in the Annual Report.

	NETHERLAND, SEWELL & ASSOCIATES, INC.
		/s/ Eric J. Stevens
	By:
		Eric J. Stevens, P.E.
		President and Chief Operating Officer
Dallas, Texas
March 19, 2024

diversifiedenergycompany

March 4, 2024 Mr. Bradley G. Gray Diversified Energy Company PLC 1800 Corporate Drive Birmingham, Alabama 35242 Dear Mr. Gray: In accordance with your request, we have estimated the proved reserves and future revenue, as of December 31, 2023, to the Diversified Energy Company PLC (DEC) interest in certain oil and gas properties located in the Appalachian Basin and the Louisiana-Oklahoma-Texas Area of the United States. We completed our evaluation on or about the date of this letter. It is our understanding that the proved reserves estimated in this report constitute all of the proved reserves owned by DEC. The estimates in this report have been prepared in accordance with the definitions and regulations of the U.S. Securities and Exchange Commission (SEC) and conform to the FASB Accounting Standards Codification Topic 932, Extractive Activities—Oil and Gas, except that future income taxes are excluded for all properties and, as requested, per-well overhead expenses are excluded for the operated properties. Definitions are presented immediately following this letter. This report has been prepared for DEC's use in filing with the SEC; in our opinion the assumptions, data, methods, and procedures used in the preparation of this report are appropriate for such purpose. As requested, this report is broken out by DEC operating areas organized into depletion pools, as provided by DEC. We estimate the net reserves and future net revenue to the DEC interest in these properties, as of December 31, 2023, to be: Net Reserves Future Net Revenue (M$) Oil NGL Gas Oil Equivalent Present Worth Depletion Pool/Category (MBBL) (MBBL) (MMCF) (MBOE) Total at 10% Appalachia Proved Developed Producing 5,288.9 69,813.6 2,346,510.4 466,187.6 2,399,043.5 1,394,723.7 Proved Developed Non-Producing(1) 0.0 0.0 6,422.2 1,070.4 3,816.3 -777.1 Total Proved Developed 5,288.9 69,813.6 2,352,932.6 467,257.9 2,402,859.9 1,393,946.6 Barnett Proved Developed Producing 296.2 11,354.5 246,639.2 52,757.2 0,340,178.7 178,858.6 Haynesville, Bossier, and Cotton Valley Proved Developed Producing 1,321.1 4,997.3 378,254.6 69,360.9 422,253.4 278,670.1 Proved Undeveloped 236.2 1,310.0 15,545.0 4,137.0 48,947.1 25,558.6 Total Proved 1,557.3 6,307.3 393,799.5 73,497.8 471,200.4 304,228.7 Mid-Continent Proved Developed Producing 5,473.6 8,225.8 206,672.4 48,144.9 404,093.2 262,656.4 Total – All Depletion Pools Proved Developed Producing 12,379.9 94,391.2 3,178,076.6 636,450.5 3,565,568.8 2,114,908.8 Proved Developed Non-Producing(1) 0.0 0.0 6,422.2 1,070.4 3,816.3 -777.1 Total Proved Developed 12,379.9 94,391.2 3,184,498.8 637,520.9 3,569,385.1 2,114,131.7 Proved Undeveloped 236.2 1,310.0 15,545.0 4,137.0 48,947.1 25,558.6 Total Proved 12,616.1 95,701.1 3,200,043.8 641,657.9 3,618,332.2 2,139,690.3 Totals may not add because of rounding. (1) Future net revenue is negative after deducting the estimated costs to return KSP field to production. The oil volumes shown include crude oil and condensate. Oil and natural gas liquids (NGL) volumes are expressed in thousands of barrels (MBBL); a barrel is equivalent to 42 United States gallons. Gas volumes are expressed in

millions of cubic feet (MMCF) at standard temperature and pressure bases. Oil equivalent volumes are expressed in thousands of barrels of oil equivalent (MBOE), determined using the ratio of 6 MCF of gas to 1 barrel of oil. Reserves categorization conveys the relative degree of certainty; reserves subcategorization is based on development and production status. No study was made to determine whether probable or possible reserves might be established for these properties. Included in this report are four proved undeveloped wells that were in the process of being drilled and completed as of December 31, 2023. The estimates of reserves and future revenue included herein have not been adjusted for risk. This report does not include any value that could be attributed to interests in undeveloped acreage beyond those tracts for which undeveloped reserves have been estimated. Gross revenue is DEC's share of the gross (100 percent) revenue from the properties prior to any deductions. Future net revenue is after deductions for DEC's share of production taxes, ad valorem taxes, capital costs, abandonment costs, and operating expenses but before consideration of any income taxes. The future net revenue has been discounted at an annual rate of 10 percent to determine its present worth, which is shown to indicate the effect of time on the value of money. Future net revenue presented in this report, whether discounted or undiscounted, should not be construed as being the fair market value of the properties. Prices used in this report are based on the 12-month unweighted arithmetic average of the first-day-of-the-month price for each month in the period January through December 2023. For oil and NGL volumes, the average West Texas Intermediate spot price of $78.21 per barrel is adjusted for quality, transportation fees, and market differentials. For gas volumes, the average Henry Hub spot price of $2.637 per MMBTU is adjusted for energy content, transportation fees, and market differentials. All prices are held constant throughout the lives of the properties. The average adjusted product prices weighted by production over the remaining lives of the properties are $71.89 per barrel of oil, $21.59 per barrel of NGL, and $2.485 per MCF of gas. Operating costs used in this report are based on operating expense records of DEC. For the nonoperated properties, these costs include the per-well overhead expenses allowed under joint operating agreements along with estimates of costs to be incurred at and below the district and field levels. As requested, operating costs for the operated properties include only direct lease- and field-level costs. Operating costs have been divided into per-well costs and per-unit-of-production costs. For all properties, headquarters general and administrative overhead expenses of DEC are not included. This report includes additional operating expenses for the effects of all applicable firm transportation contracts. It is our understanding that DEC is supplying all committed volumes for these contracts. Operating costs are not escalated for inflation. Capital costs used in this report were provided by DEC and are based on authorizations for expenditure and actual costs from recent activity. Capital costs are included as required for artificial lift, workovers, new development wells, production equipment, and midstream facility maintenance. Based on our understanding of future development plans, a review of the records provided to us, and our knowledge of similar properties, we regard these estimated capital costs to be reasonable. Abandonment costs used in this report are DEC's estimates of the costs to abandon the wells and production facilities, net of any salvage value. Capital costs and abandonment costs are not escalated for inflation. For the purposes of this report, we did not perform any field inspection of the properties, nor did we examine the mechanical operation or condition of the wells and facilities. We have not investigated possible environmental liability related to the properties; therefore, our estimates do not include any costs due to such possible liability. We have made no investigation of potential volume and value imbalances resulting from overdelivery or underdelivery to the DEC interest. Therefore, our estimates of reserves and future revenue do not include adjustments for the settlement of any such imbalances; our projections are based on DEC receiving its net revenue interest share of estimated future gross production. In addition, no consideration has been given to any potential future gas curtailment activities or changes in market conditions. The reserves shown in this report are estimates only and should not be construed as exact quantities. Proved reserves are those quantities of oil and gas which, by analysis of engineering and geoscience data, can be estimated with reasonable certainty to be economically producible; probable and possible reserves are those

additional reserves which are sequentially less certain to be recovered than proved reserves. Estimates of reserves may increase or decrease as a result of market conditions, future operations, changes in regulations, or actual reservoir performance. In addition to the primary economic assumptions discussed herein, our estimates are based on certain assumptions including, but not limited to, that the properties will be developed consistent with current development plans as provided to us by DEC, that the properties will be operated in a prudent manner, that no governmental regulations or controls will be put in place that would impact the ability of the interest owner to recover the reserves, and that our projections of future production will prove consistent with actual performance. If the reserves are recovered, the revenues therefrom and the costs related thereto could be more or less than the estimated amounts. Because of governmental policies and uncertainties of supply and demand, the sales rates, prices received for the reserves, and costs incurred in recovering such reserves may vary from assumptions made while preparing this report. For the purposes of this report, we used technical and economic data including, but not limited to, well logs, geologic maps, well test data, production data, historical price and cost information, and property ownership interests. The reserves in this report have been estimated using deterministic methods; these estimates have been prepared in accordance with the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the Society of Petroleum Engineers (SPE Standards). We used standard engineering and geoscience methods, or a combination of methods, including performance analysis, volumetric analysis, and analogy, that we considered to be appropriate and necessary to categorize and estimate reserves in accordance with SEC definitions and regulations. As in all aspects of oil and gas evaluation, there are uncertainties inherent in the interpretation of engineering and geoscience data; therefore, our conclusions necessarily represent only informed professional judgment. The data used in our estimates were obtained from DEC, public data sources, and the nonconfidential files of Netherland, Sewell & Associates, Inc. (NSAI) and were accepted as accurate. Supporting work data are on file in our office. We have not examined the titles to the properties or independently confirmed the actual degree or type of interest owned. The technical persons primarily responsible for preparing the estimates presented herein meet the requirements regarding qualifications, independence, objectivity, and confidentiality set forth in the SPE Standards. Robert C. Barg, a Licensed Professional Engineer in the State of Texas, has been practicing consulting petroleum engineering at NSAI since 1989 and has over 6 years of prior industry experience. William J. Knights, a Licensed Professional Geoscientist in the State of Texas, has been practicing consulting petroleum geoscience at NSAI since 1991 and has over 10 years of prior industry experience. We are independent petroleum engineers, geologists, geophysicists, and petrophysicists; we do not own an interest in these properties nor are we employed on a contingent basis. Sincerely, NETHERLAND, SEWELL & ASSOCIATES, INC. Texas Registered Engineering Firm F-2699 By: Richard B. Talley, Jr., P.E. Chief Executive Officer By: By: Robert C. Barg, P.E. 71658 William J. Knights, P.G. 1532 Senior Vice President Vice President Date Signed: March 4, 2024 Date Signed: March 4, 2024 RCB:DCC

DEFINITIONS OF OIL AND GAS RESERVES Adapted from U.S. Securities and Exchange Commission Regulation S-X Section 210.4-10(a) Definitions - Page 1 of 6 The following definitions are set forth in U.S. Securities and Exchange Commission (SEC) Regulation S-X Section 210.4-10(a). Also included is supplemental information from (1) the 2018 Petroleum Resources Management System approved by the Society of Petroleum Engineers, (2) the FASB Accounting Standards Codification Topic 932, Extractive Activities—Oil and Gas, and (3) the SEC's Compliance and Disclosure Interpretations. (1) Acquisition of properties. Costs incurred to purchase, lease or otherwise acquire a property, including costs of lease bonuses and options to purchase or lease properties, the portion of costs applicable to minerals when land including mineral rights is purchased in fee, brokers' fees, recording fees, legal costs, and other costs incurred in acquiring properties. (2) Analogous reservoir. Analogous reservoirs, as used in resources assessments, have similar rock and fluid properties, reservoir conditions (depth, temperature, and pressure) and drive mechanisms, but are typically at a more advanced stage of development than the reservoir of interest and thus may provide concepts to assist in the interpretation of more limited data and estimation of recovery. When used to support proved reserves, an "analogous reservoir" refers to a reservoir that shares the following characteristics with the reservoir of interest: (i) Same geological formation (but not necessarily in pressure communication with the reservoir of interest); (ii) Same environment of deposition; (iii) Similar geological structure; and (iv) Same drive mechanism. Instruction to paragraph (a)(2): Reservoir properties must, in the aggregate, be no more favorable in the analog than in the reservoir of interest. (3) Bitumen. Bitumen, sometimes referred to as natural bitumen, is petroleum in a solid or semi-solid state in natural deposits with a viscosity greater than 10,000 centipoise measured at original temperature in the deposit and atmospheric pressure, on a gas free basis. In its natural state it usually contains sulfur, metals, and other non-hydrocarbons. (4) Condensate. Condensate is a mixture of hydrocarbons that exists in the gaseous phase at original reservoir temperature and pressure, but that, when produced, is in the liquid phase at surface pressure and temperature. (5) Deterministic estimate. The method of estimating reserves or resources is called deterministic when a single value for each parameter (from the geoscience, engineering, or economic data) in the reserves calculation is used in the reserves estimation procedure. (6) Developed oil and gas reserves. Developed oil and gas reserves are reserves of any category that can be expected to be recovered: (i) Through existing wells with existing equipment and operating methods or in which the cost of the required equipment is relatively minor compared to the cost of a new well; and (ii) Through installed extraction equipment and infrastructure operational at the time of the reserves estimate if the extraction is by means not involving a well. Supplemental definitions from the 2018 Petroleum Resources Management System: Developed Producing Reserves – Expected quantities to be recovered from completion intervals that are open and producing at the effective date of the estimate. Improved recovery Reserves are considered producing only after the improved recovery project is in operation. Developed Non-Producing Reserves – Shut-in and behind-pipe Reserves. Shut-in Reserves are expected to be recovered from (1) completion intervals that are open at the time of the estimate but which have not yet started producing, (2) wells which were shut-in for market conditions or pipeline connections, or (3) wells not capable of production for mechanical reasons. Behind-pipe Reserves are expected to be recovered from zones in existing wells that will require additional completion work or future re-completion before start of production with minor cost to access these reserves. In all cases, production can be initiated or restored with relatively low expenditure compared to the cost of drilling a new well. (7) Development costs. Costs incurred to obtain access to proved reserves and to provide facilities for extracting, treating, gathering and storing the oil and gas. More specifically, development costs, including depreciation and applicable operating costs of support equipment and facilities and other costs of development activities, are costs incurred to: (i) Gain access to and prepare well locations for drilling, including surveying well locations for the purpose of determining specific development drilling sites, clearing ground, draining, road building, and relocating public roads, gas lines, and power lines, to the extent necessary in developing the proved reserves. (ii) Drill and equip development wells, development-type stratigraphic test wells, and service wells, including the costs of platforms and of well equipment such as casing, tubing, pumping equipment, and the wellhead assembly.

DEFINITIONS OF OIL AND GAS RESERVES Adapted from U.S. Securities and Exchange Commission Regulation S-X Section 210.4-10(a) Definitions - Page 2 of 6 (iii) Acquire, construct, and install production facilities such as lease flow lines, separators, treaters, heaters, manifolds, measuring devices, and production storage tanks, natural gas cycling and processing plants, and central utility and waste disposal systems. (iv) Provide improved recovery systems. (8) Development project. A development project is the means by which petroleum resources are brought to the status of economically producible. As examples, the development of a single reservoir or field, an incremental development in a producing field, or the integrated development of a group of several fields and associated facilities with a common ownership may constitute a development project. (9) Development well. A well drilled within the proved area of an oil or gas reservoir to the depth of a stratigraphic horizon known to be productive. (10) Economically producible. The term economically producible, as it relates to a resource, means a resource which generates revenue that exceeds, or is reasonably expected to exceed, the costs of the operation. The value of the products that generate revenue shall be determined at the terminal point of oil and gas producing activities as defined in paragraph (a)(16) of this section. (11) Estimated ultimate recovery (EUR). Estimated ultimate recovery is the sum of reserves remaining as of a given date and cumulative production as of that date. (12) Exploration costs. Costs incurred in identifying areas that may warrant examination and in examining specific areas that are considered to have prospects of containing oil and gas reserves, including costs of drilling exploratory wells and exploratory- type stratigraphic test wells. Exploration costs may be incurred both before acquiring the related property (sometimes referred to in part as prospecting costs) and after acquiring the property. Principal types of exploration costs, which include depreciation and applicable operating costs of support equipment and facilities and other costs of exploration activities, are: (i) Costs of topographical, geographical and geophysical studies, rights of access to properties to conduct those studies, and salaries and other expenses of geologists, geophysical crews, and others conducting those studies. Collectively, these are sometimes referred to as geological and geophysical or "G&G" costs. (ii) Costs of carrying and retaining undeveloped properties, such as delay rentals, ad valorem taxes on properties, legal costs for title defense, and the maintenance of land and lease records. (iii) Dry hole contributions and bottom hole contributions. (iv) Costs of drilling and equipping exploratory wells. (v) Costs of drilling exploratory-type stratigraphic test wells. (13) Exploratory well. An exploratory well is a well drilled to find a new field or to find a new reservoir in a field previously found to be productive of oil or gas in another reservoir. Generally, an exploratory well is any well that is not a development well, an extension well, a service well, or a stratigraphic test well as those items are defined in this section. (14) Extension well. An extension well is a well drilled to extend the limits of a known reservoir. (15) Field. An area consisting of a single reservoir or multiple reservoirs all grouped on or related to the same individual geological structural feature and/or stratigraphic condition. There may be two or more reservoirs in a field which are separated vertically by intervening impervious strata, or laterally by local geologic barriers, or by both. Reservoirs that are associated by being in overlapping or adjacent fields may be treated as a single or common operational field. The geological terms "structural feature" and "stratigraphic condition" are intended to identify localized geological features as opposed to the broader terms of basins, trends, provinces, plays, areas-of-interest, etc. (16) Oil and gas producing activities. (i) Oil and gas producing activities include: (A) The search for crude oil, including condensate and natural gas liquids, or natural gas ("oil and gas") in their natural states and original locations; (B) The acquisition of property rights or properties for the purpose of further exploration or for the purpose of removing the oil or gas from such properties; (C) The construction, drilling, and production activities necessary to retrieve oil and gas from their natural reservoirs, including the acquisition, construction, installation, and maintenance of field gathering and storage systems, such as: (1) Lifting the oil and gas to the surface; and (2) Gathering, treating, and field processing (as in the case of processing gas to extract liquid hydrocarbons); and

DEFINITIONS OF OIL AND GAS RESERVES Adapted from U.S. Securities and Exchange Commission Regulation S-X Section 210.4-10(a) Definitions - Page 3 of 6 (D) Extraction of saleable hydrocarbons, in the solid, liquid, or gaseous state, from oil sands, shale, coalbeds, or other nonrenewable natural resources which are intended to be upgraded into synthetic oil or gas, and activities undertaken with a view to such extraction. Instruction 1 to paragraph (a)(16)(i): The oil and gas production function shall be regarded as ending at a "terminal point", which is the outlet valve on the lease or field storage tank. If unusual physical or operational circumstances exist, it may be appropriate to regard the terminal point for the production function as: a. The first point at which oil, gas, or gas liquids, natural or synthetic, are delivered to a main pipeline, a common carrier, a refinery, or a marine terminal; and b. In the case of natural resources that are intended to be upgraded into synthetic oil or gas, if those natural resources are delivered to a purchaser prior to upgrading, the first point at which the natural resources are delivered to a main pipeline, a common carrier, a refinery, a marine terminal, or a facility which upgrades such natural resources into synthetic oil or gas. Instruction 2 to paragraph (a)(16)(i): For purposes of this paragraph (a)(16), the term saleable hydrocarbons means hydrocarbons that are saleable in the state in which the hydrocarbons are delivered. (ii) Oil and gas producing activities do not include: (A) Transporting, refining, or marketing oil and gas; (B) Processing of produced oil, gas, or natural resources that can be upgraded into synthetic oil or gas by a registrant that does not have the legal right to produce or a revenue interest in such production; (C) Activities relating to the production of natural resources other than oil, gas, or natural resources from which synthetic oil and gas can be extracted; or (D) Production of geothermal steam. (17) Possible reserves. Possible reserves are those additional reserves that are less certain to be recovered than probable reserves. (i) When deterministic methods are used, the total quantities ultimately recovered from a project have a low probability of exceeding proved plus probable plus possible reserves. When probabilistic methods are used, there should be at least a 10% probability that the total quantities ultimately recovered will equal or exceed the proved plus probable plus possible reserves estimates. (ii) Possible reserves may be assigned to areas of a reservoir adjacent to probable reserves where data control and interpretations of available data are progressively less certain. Frequently, this will be in areas where geoscience and engineering data are unable to define clearly the area and vertical limits of commercial production from the reservoir by a defined project. (iii) Possible reserves also include incremental quantities associated with a greater percentage recovery of the hydrocarbons in place than the recovery quantities assumed for probable reserves. (iv) The proved plus probable and proved plus probable plus possible reserves estimates must be based on reasonable alternative technical and commercial interpretations within the reservoir or subject project that are clearly documented, including comparisons to results in successful similar projects. (v) Possible reserves may be assigned where geoscience and engineering data identify directly adjacent portions of a reservoir within the same accumulation that may be separated from proved areas by faults with displacement less than formation thickness or other geological discontinuities and that have not been penetrated by a wellbore, and the registrant believes that such adjacent portions are in communication with the known (proved) reservoir. Possible reserves may be assigned to areas that are structurally higher or lower than the proved area if these areas are in communication with the proved reservoir. (vi) Pursuant to paragraph (a)(22)(iii) of this section, where direct observation has defined a highest known oil (HKO) elevation and the potential exists for an associated gas cap, proved oil reserves should be assigned in the structurally higher portions of the reservoir above the HKO only if the higher contact can be established with reasonable certainty through reliable technology. Portions of the reservoir that do not meet this reasonable certainty criterion may be assigned as probable and possible oil or gas based on reservoir fluid properties and pressure gradient interpretations. (18) Probable reserves. Probable reserves are those additional reserves that are less certain to be recovered than proved reserves but which, together with proved reserves, are as likely as not to be recovered. (i) When deterministic methods are used, it is as likely as not that actual remaining quantities recovered will exceed the sum of estimated proved plus probable reserves. When probabilistic methods are used, there should be at least a 50% probability that the actual quantities recovered will equal or exceed the proved plus probable reserves estimates.

DEFINITIONS OF OIL AND GAS RESERVES Adapted from U.S. Securities and Exchange Commission Regulation S-X Section 210.4-10(a) Definitions - Page 4 of 6 (ii) Probable reserves may be assigned to areas of a reservoir adjacent to proved reserves where data control or interpretations of available data are less certain, even if the interpreted reservoir continuity of structure or productivity does not meet the reasonable certainty criterion. Probable reserves may be assigned to areas that are structurally higher than the proved area if these areas are in communication with the proved reservoir. (iii) Probable reserves estimates also include potential incremental quantities associated with a greater percentage recovery of the hydrocarbons in place than assumed for proved reserves. (iv) See also guidelines in paragraphs (a)(17)(iv) and (a)(17)(vi) of this section. (19) Probabilistic estimate. The method of estimation of reserves or resources is called probabilistic when the full range of values that could reasonably occur for each unknown parameter (from the geoscience and engineering data) is used to generate a full range of possible outcomes and their associated probabilities of occurrence. (20) Production costs. (i) Costs incurred to operate and maintain wells and related equipment and facilities, including depreciation and applicable operating costs of support equipment and facilities and other costs of operating and maintaining those wells and related equipment and facilities. They become part of the cost of oil and gas produced. Examples of production costs (sometimes called lifting costs) are: (A) Costs of labor to operate the wells and related equipment and facilities. (B) Repairs and maintenance. (C) Materials, supplies, and fuel consumed and supplies utilized in operating the wells and related equipment and facilities. (D) Property taxes and insurance applicable to proved properties and wells and related equipment and facilities. (E) Severance taxes. (ii) Some support equipment or facilities may serve two or more oil and gas producing activities and may also serve transportation, refining, and marketing activities. To the extent that the support equipment and facilities are used in oil and gas producing activities, their depreciation and applicable operating costs become exploration, development or production costs, as appropriate. Depreciation, depletion, and amortization of capitalized acquisition, exploration, and development costs are not production costs but also become part of the cost of oil and gas produced along with production (lifting) costs identified above. (21) Proved area. The part of a property to which proved reserves have been specifically attributed. (22) Proved oil and gas reserves. Proved oil and gas reserves are those quantities of oil and gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible—from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations—prior to the time at which contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. The project to extract the hydrocarbons must have commenced or the operator must be reasonably certain that it will commence the project within a reasonable time. (i) The area of the reservoir considered as proved includes: (A) The area identified by drilling and limited by fluid contacts, if any, and (B) Adjacent undrilled portions of the reservoir that can, with reasonable certainty, be judged to be continuous with it and to contain economically producible oil or gas on the basis of available geoscience and engineering data. (ii) In the absence of data on fluid contacts, proved quantities in a reservoir are limited by the lowest known hydrocarbons (LKH) as seen in a well penetration unless geoscience, engineering, or performance data and reliable technology establishes a lower contact with reasonable certainty. (iii) Where direct observation from well penetrations has defined a highest known oil (HKO) elevation and the potential exists for an associated gas cap, proved oil reserves may be assigned in the structurally higher portions of the reservoir only if geoscience, engineering, or performance data and reliable technology establish the higher contact with reasonable certainty. (iv) Reserves which can be produced economically through application of improved recovery techniques (including, but not limited to, fluid injection) are included in the proved classification when: (A) Successful testing by a pilot project in an area of the reservoir with properties no more favorable than in the reservoir as a whole, the operation of an installed program in the reservoir or an analogous reservoir, or other evidence using reliable technology establishes the reasonable certainty of the engineering analysis on which the project or program was based; and

DEFINITIONS OF OIL AND GAS RESERVES Adapted from U.S. Securities and Exchange Commission Regulation S-X Section 210.4-10(a) Definitions - Page 5 of 6 (B) The project has been approved for development by all necessary parties and entities, including governmental entities. (v) Existing economic conditions include prices and costs at which economic producibility from a reservoir is to be determined. The price shall be the average price during the 12-month period prior to the ending date of the period covered by the report, determined as an unweighted arithmetic average of the first-day-of-the-month price for each month within such period, unless prices are defined by contractual arrangements, excluding escalations based upon future conditions. (23) Proved properties. Properties with proved reserves. (24) Reasonable certainty. If deterministic methods are used, reasonable certainty means a high degree of confidence that the quantities will be recovered. If probabilistic methods are used, there should be at least a 90% probability that the quantities actually recovered will equal or exceed the estimate. A high degree of confidence exists if the quantity is much more likely to be achieved than not, and, as changes due to increased availability of geoscience (geological, geophysical, and geochemical), engineering, and economic data are made to estimated ultimate recovery (EUR) with time, reasonably certain EUR is much more likely to increase or remain constant than to decrease. (25) Reliable technology. Reliable technology is a grouping of one or more technologies (including computational methods) that has been field tested and has been demonstrated to provide reasonably certain results with consistency and repeatability in the formation being evaluated or in an analogous formation. (26) Reserves. Reserves are estimated remaining quantities of oil and gas and related substances anticipated to be economically producible, as of a given date, by application of development projects to known accumulations. In addition, there must exist, or there must be a reasonable expectation that there will exist, the legal right to produce or a revenue interest in the production, installed means of delivering oil and gas or related substances to market, and all permits and financing required to implement the project. Note to paragraph (a)(26): Reserves should not be assigned to adjacent reservoirs isolated by major, potentially sealing, faults until those reservoirs are penetrated and evaluated as economically producible. Reserves should not be assigned to areas that are clearly separated from a known accumulation by a non-productive reservoir (i.e., absence of reservoir, structurally low reservoir, or negative test results). Such areas may contain prospective resources (i.e., potentially recoverable resources from undiscovered accumulations). Excerpted from the FASB Accounting Standards Codification Topic 932, Extractive Activities—Oil and Gas: 932-235-50-30 A standardized measure of discounted future net cash flows relating to an entity's interests in both of the following shall be disclosed as of the end of the year: a. Proved oil and gas reserves (see paragraphs 932-235-50-3 through 50-11B) b. Oil and gas subject to purchase under long-term supply, purchase, or similar agreements and contracts in which the entity participates in the operation of the properties on which the oil or gas is located or otherwise serves as the producer of those reserves (see paragraph 932-235-50-7). The standardized measure of discounted future net cash flows relating to those two types of interests in reserves may be combined for reporting purposes. 932-235-50-31 All of the following information shall be disclosed in the aggregate and for each geographic area for which reserve quantities are disclosed in accordance with paragraphs 932-235-50-3 through 50-11B: a. Future cash inflows. These shall be computed by applying prices used in estimating the entity's proved oil and gas reserves to the year-end quantities of those reserves. Future price changes shall be considered only to the extent provided by contractual arrangements in existence at year-end. b. Future development and production costs. These costs shall be computed by estimating the expenditures to be incurred in developing and producing the proved oil and gas reserves at the end of the year, based on year-end costs and assuming continuation of existing economic conditions. If estimated development expenditures are significant, they shall be presented separately from estimated production costs. c. Future income tax expenses. These expenses shall be computed by applying the appropriate year-end statutory tax rates, with consideration of future tax rates already legislated, to the future pretax net cash flows relating to the entity's proved oil and gas reserves, less the tax basis of the properties involved. The future income tax expenses shall give effect to tax deductions and tax credits and allowances relating to the entity's proved oil and gas reserves. d. Future net cash flows. These amounts are the result of subtracting future development and production costs and future income tax expenses from future cash inflows.

DEFINITIONS OF OIL AND GAS RESERVES Adapted from U.S. Securities and Exchange Commission Regulation S-X Section 210.4-10(a) Definitions - Page 6 of 6 e. Discount. This amount shall be derived from using a discount rate of 10 percent a year to reflect the timing of the future net cash flows relating to proved oil and gas reserves. f. Standardized measure of discounted future net cash flows. This amount is the future net cash flows less the computed discount. (27) Reservoir. A porous and permeable underground formation containing a natural accumulation of producible oil and/or gas that is confined by impermeable rock or water barriers and is individual and separate from other reservoirs. (28) Resources. Resources are quantities of oil and gas estimated to exist in naturally occurring accumulations. A portion of the resources may be estimated to be recoverable, and another portion may be considered to be unrecoverable. Resources include both discovered and undiscovered accumulations. (29) Service well. A well drilled or completed for the purpose of supporting production in an existing field. Specific purposes of service wells include gas injection, water injection, steam injection, air injection, salt-water disposal, water supply for injection, observation, or injection for in-situ combustion. (30) Stratigraphic test well. A stratigraphic test well is a drilling effort, geologically directed, to obtain information pertaining to a specific geologic condition. Such wells customarily are drilled without the intent of being completed for hydrocarbon production. The classification also includes tests identified as core tests and all types of expendable holes related to hydrocarbon exploration. Stratigraphic tests are classified as "exploratory type" if not drilled in a known area or "development type" if drilled in a known area. (31) Undeveloped oil and gas reserves. Undeveloped oil and gas reserves are reserves of any category that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required for recompletion. (i) Reserves on undrilled acreage shall be limited to those directly offsetting development spacing areas that are reasonably certain of production when drilled, unless evidence using reliable technology exists that establishes reasonable certainty of economic producibility at greater distances. (ii) Undrilled locations can be classified as having undeveloped reserves only if a development plan has been adopted indicating that they are scheduled to be drilled within five years, unless the specific circumstances, justify a longer time. From the SEC's Compliance and Disclosure Interpretations (October 26, 2009): Although several types of projects — such as constructing offshore platforms and development in urban areas, remote locations or environmentally sensitive locations — by their nature customarily take a longer time to develop and therefore often do justify longer time periods, this determination must always take into consideration all of the facts and circumstances. No particular type of project per se justifies a longer time period, and any extension beyond five years should be the exception, and not the rule. Factors that a company should consider in determining whether or not circumstances justify recognizing reserves even though development may extend past five years include, but are not limited to, the following:  The company's level of ongoing significant development activities in the area to be developed (for example, drilling only the minimum number of wells necessary to maintain the lease generally would not constitute significant development activities);  The company's historical record at completing development of comparable long-term projects;  The amount of time in which the company has maintained the leases, or booked the reserves, without significant development activities;  The extent to which the company has followed a previously adopted development plan (for example, if a company has changed its development plan several times without taking significant steps to implement any of those plans, recognizing proved undeveloped reserves typically would not be appropriate); and  The extent to which delays in development are caused by external factors related to the physical operating environment (for example, restrictions on development on Federal lands, but not obtaining government permits), rather than by internal factors (for example, shifting resources to develop properties with higher priority). (iii) Under no circumstances shall estimates for undeveloped reserves be attributable to any acreage for which an application of fluid injection or other improved recovery technique is contemplated, unless such techniques have been proved effective by actual projects in the same reservoir or an analogous reservoir, as defined in paragraph (a)(2) of this section, or by other evidence using reliable technology establishing reasonable certainty. (32) Unproved properties. Properties with no proved reserves.

Document

Exhibit 99.1

DIVERSIFIED ENERGY COMPANY PLC

POLICY FOR RECOVERY OF ERRONEOUSLY AWARDED COMPENSATION

Diversified Energy Company plc (the “Company”) has adopted this Policy for Recovery of Erroneously Awarded Compensation (the “Policy”), effective as of December 11, 2023 (the “Effective Date”). Capitalized terms used in this Policy but not otherwise defined herein are defined in Section 11.

1.Persons Subject to Policy

This Policy shall apply to current and former Officers.

2.Compensation Subject to Policy

This Policy shall apply to Incentive-Based Compensation received on or after the Effective Date. For purposes of this Policy, the date on which Incentive-Based Compensation is “received” shall be determined under the Applicable Rules, which generally provide that Incentive-Based Compensation is “received” in the Company’s fiscal period during which the relevant Financial Reporting Measure is attained or satisfied, without regard to whether the grant, vesting or payment of the Incentive-Based Compensation occurs after the end of that period.

3.Recovery of Compensation

In the event that the Company is required to prepare a Restatement, the Company shall recover, reasonably promptly, the portion of any Incentive-Based Compensation that is Erroneously Awarded Compensation, unless the Committee has determined that recovery would be Impracticable. Recovery shall be required in accordance with the preceding sentence regardless of whether the applicable Officer engaged in misconduct or otherwise caused or contributed to the requirement for the Restatement and regardless of whether or when restated financial statements are filed by the Company. For clarity, the recovery of Erroneously Awarded Compensation under this Policy will not give rise to any person’s right to voluntarily terminate employment for “good reason,” or due to a “constructive termination” (or any similar term of like effect) under any plan, program or policy of or agreement with the Company or any of its affiliates.

4.Manner of Recovery; Limitation on Duplicative Recovery

The Committee shall, in its sole discretion, determine the manner of recovery of any Erroneously Awarded Compensation, which may include, without limitation, reduction or cancellation by the Company or an affiliate of the Company of Incentive-Based Compensation, Erroneously Awarded Compensation or solely time-vesting equity awards, reimbursement or repayment by any person subject to this Policy of the Erroneously Awarded Compensation, and, to the extent permitted by law, an offset of the Erroneously Awarded Compensation against other compensation payable by the Company or an affiliate of the Company to such person. Notwithstanding the foregoing, unless otherwise prohibited by the Applicable Rules, to the extent this Policy provides for recovery of Erroneously Awarded Compensation already recovered by the Company pursuant to Section 304 of the Sarbanes-Oxley Act of 2022 or Other Recovery Arrangements, the amount of Erroneously Awarded Compensation already recovered by the Company from the recipient of such Erroneously Awarded Compensation may be credited to the amount of Erroneously Awarded Compensation required to be recovered pursuant to this Policy from such person.

5.Administration

This Policy shall be administered, interpreted and construed by the Committee, which is authorized to make all determinations necessary, appropriate or advisable for such purpose. The Board may re-vest in itself the authority to administer, interpret and construe this Policy in accordance with applicable law, and in such event references herein to the “Committee” shall be deemed to be references to the Board. Subject to any permitted review by the applicable national securities exchange or association pursuant to the Applicable Rules, all determinations and decisions made by the Committee pursuant to the provisions of this Policy shall be final, conclusive and binding on all persons, including the Company and its affiliates, equityholders and employees. The Committee may delegate administrative duties with respect to this Policy to one or more directors or employees of the Company, as permitted under applicable law, including any Applicable Rules.

6.Interpretation

This Policy shall be interpreted and applied in a manner that is consistent with the requirements of the Applicable Rules, and to the extent this Policy is inconsistent with such Applicable Rules, it shall be deemed amended to the minimum extent necessary to ensure compliance therewith.

7.No Indemnification; No Liability

The Company shall not indemnify or insure any person against the loss of any Erroneously Awarded Compensation pursuant to this Policy, nor shall the Company directly or indirectly pay or reimburse any person for any premiums for third-party insurance policies that such person may elect to purchase to fund such person’s potential obligations under this Policy. None of the Company, an affiliate of the Company or any member of the Committee or the Board shall have any liability to any person as a result of actions taken under this Policy.

8.Application; Enforceability

Except as otherwise determined by the Committee or the Board, the adoption of this Policy does not limit, and is intended to apply in addition to, any other clawback, recoupment, forfeiture or similar policies or provisions of the Company or its affiliates, including any such policies or provisions of such effect contained in any employment agreement, bonus plan, incentive plan, equity-based plan or award agreement thereunder or similar plan, program or agreement of the Company or an affiliate or required under applicable law (the “Other Recovery Arrangements”). The remedy specified in this Policy shall not be exclusive and shall be in addition to every other right or remedy at law or in equity that may be available to the Company or an affiliate of the Company.

9.Severability

The provisions in this Policy are intended to be applied to the fullest extent of the law; provided, however, to the extent that any provision of this Policy is found to be unenforceable or invalid under any applicable law, such provision will be applied to the maximum extent permitted, and shall automatically be deemed amended in a manner consistent with its objectives to the extent necessary to conform to any limitations required under applicable law.

10.Amendment and Termination

Exhibit 99.1

The Board or the Committee may amend, modify or terminate this Policy in whole or in part at any time and from time to time in its sole discretion. This Policy will terminate automatically when the Company does not have a class of securities listed on a national securities exchange or association.

11.Definitions

“Applicable Rules” means Section 10D of the Exchange Act, Rule 10D-1 promulgated thereunder, the listing rules of the national securities exchange or association on which the Company’s securities are listed, and any applicable rules, standards or other guidance adopted by the Securities and Exchange Commission or any national securities exchange or association on which the Company’s securities are listed.

“Board” means the Board of Directors of the Company.

“Committee” means the committee of the Board responsible for executive compensation decisions comprised solely of independent directors (as determined under the Applicable Rules) or, in the absence of such a committee, a majority of the independent directors serving on the Board.

“Erroneously Awarded Compensation” means the pretax amount of Incentive-Based Compensation received by a current or former Officer that exceeds the amount of Incentive-Based Compensation that would have been received by such current or former Officer based on a restated Financial Reporting Measure, as determined in accordance with the Applicable Rules.

“Exchange Act” means the Securities Exchange Act of 1934, as amended.

“Financial Reporting Measure” means any measure determined and presented in accordance with the accounting principles used in preparing the Company’s financial statements, and any measures derived wholly or in part from such measures, including GAAP, IFRS and non-GAAP/IFRS financial measures, as well as stock or share price and total equityholder return.

“GAAP” means United States generally accepted accounting principles.

“IFRS” means international financial reporting standards as adopted by the International Accounting Standards Board.

“Impracticable” means (a) the direct costs paid to third parties to assist in enforcing recovery would exceed the Erroneously Awarded Compensation; provided that the Company has (i) made reasonable attempt(s) to recover the Erroneously Awarded Compensation, (ii) documented such attempts and (iii) provided such documentation to the relevant listing exchange or association, (b) to the extent permitted by the Applicable Rules, the recovery would violate the Company’s home country laws pursuant to an opinion of home country counsel; provided that the Company has (i) obtained an opinion of home country counsel, acceptable to the relevant listing exchange or association, that recovery would result in such violation and (ii) provided such opinion to the relevant listing exchange or association, or (c) recovery would likely cause an otherwise tax-qualified retirement plan, under which benefits are broadly available to employees of the Company, to fail to meet the requirements of 26 U.S.C. 401(a)(13) or 26 U.S.C. 411(a) and the regulations thereunder.

“Incentive-Based Compensation” means, with respect to a Restatement, any compensation that is granted, earned, or vested based wholly or in part upon the attainment of one or more Financial Reporting Measures and received by a person: (a) after such person began service as an Officer; (b) who served as an Officer at any time during the performance period for that compensation; (c) while the Company has a class of securities listed on a national securities exchange or association; and (d) during the applicable Three-Year Period.

“Officer” means each person who the Company determines serves as a Company officer, as defined in Section 16 of the Securities Exchange Act of 1934, as amended.

“Restatement” means an accounting restatement to correct the Company’s material noncompliance with any financial reporting requirement under securities laws, including restatements that correct an error in previously issued financial statements (a) that is material to the previously issued financial statements or (b) that would result in a material misstatement if the error were corrected in the current period or left uncorrected in the current period.

“Three-Year Period” means, with respect to a Restatement, the three completed fiscal years immediately preceding the date that the Board, a committee of the Board, or the officer or officers of the Company authorized to take such action if Board action is not required, concludes, or reasonably should have concluded, that the Company is required to prepare such Restatement, or, if earlier, the date on which a court, regulator or other legally authorized body directs the Company to prepare such Restatement. The “Three-Year Period” also includes any transition period (that results from a change in the Company’s fiscal year) within or immediately following the three completed fiscal years identified in the preceding sentence. However, a transition period between the last day of the Company’s previous fiscal year end and the first day of its new fiscal year that comprises a period of nine to 12 months shall be deemed a completed fiscal year.