10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

(Mark One)


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

For the quarterly period ended March 31, 2023


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

Commission File Number 001-32318

DEVON ENERGY CORPORATION

(Exact name of registrant as specified in its charter)


Delaware		73-1567067
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer identification No.)

333 West Sheridan Avenue, Oklahoma City, Oklahoma		73102-5015
(Address of principal executive offices)		(Zip code)

Registrant’s telephone number, including area code: (405) 235-3611

Former name, address and former fiscal year, if changed from last report: Not applicable

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


Title of each class	Trading Symbol	Name of each exchange on which registered
Common Stock, par value $0.10 per share	DVN	The New York Stock Exchange

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 ☑ 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 ☑ No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.


Large accelerated filer	☑	Accelerated filer	☐	Non-accelerated filer	☐
Smaller reporting company	☐	Emerging growth company	☐

If an emerging growth company, 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 is a shell company (as defined in Rule 12b-2 of the Act). Yes ☐ No ☑

On April 26, 2023, 641.7 million shares of common stock were outstanding.

Table of Contents

DEVON ENERGY CORPORATION

FORM 10-Q

TABLE OF CONTENTS


Part I. Financial Information
Item 1.	Financial Statements	6
	Consolidated Statements of Comprehensive Earnings	6
	Consolidated Balance Sheets	7
	Consolidated Statements of Cash Flows	8
	Consolidated Statements of Equity	9
	Notes to Consolidated Financial Statements	10
	Note 1 – Summary of Significant Accounting Policies	10
	Note 2 – Acquisitions and Divestitures	11
	Note 3 – Derivative Financial Instruments	11
	Note 4 – Share-Based Compensation	13
	Note 5 – Restructuring	14
	Note 6 – Other, Net	14
	Note 7 – Income Taxes	15
	Note 8 – Net Earnings Per Share	15
	Note 9 – Other Comprehensive Earnings (Loss)	16
	Note 10 – Supplemental Information to Statements of Cash Flows	16
	Note 11 – Accounts Receivable	16
	Note 12 – Property, Plant and Equipment	17
	Note 13 – Debt and Related Expenses	17
	Note 14 – Leases	18
	Note 15 – Asset Retirement Obligations	18
	Note 16 – Stockholders’ Equity	19
	Note 17 – Commitments and Contingencies	19
	Note 18 – Fair Value Measurements	21
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	22
	Executive Overview	22
	Results of Operations	23
	Capital Resources, Uses and Liquidity	30
	Critical Accounting Estimates	33
	Non-GAAP Measures	33
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	35
Item 4.	Controls and Procedures	35

Part II. Other Information
Item 1.	Legal Proceedings	36
Item 1A.	Risk Factors	36
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	36
Item 3.	Defaults Upon Senior Securities	36
Item 4.	Mine Safety Disclosures	36
Item 5.	Other Information	36
Item 6.	Exhibits	37

Signatures		38

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DEFINITIONS

Unless the context otherwise indicates, references to “us,” “we,” “our,” “ours,” “Devon,” the “Company” and “Registrant” refer to Devon Energy Corporation and its consolidated subsidiaries. All monetary values, other than per unit and per share amounts, are stated in millions of U.S. dollars unless otherwise specified. In addition, the following are other abbreviations and definitions of certain terms used within this Quarterly Report on Form 10-Q:

"2022 Plan" means the Devon Energy Corporation 2022 Long-Term Incentive Plan.

“Bbl” or “Bbls” means barrel or barrels.

“Boe” means barrel of oil equivalent. Gas proved reserves and production are converted to Boe, at the pressure and temperature base standard of each respective state in which the gas is produced, at the rate of six Mcf of gas per Bbl of oil, based upon the approximate relative energy content of gas and oil. NGL proved reserves and production are converted to Boe on a one-to-one basis with oil.

“Btu” means British thermal units, a measure of heating value.

“Catalyst” means Catalyst Midstream Partners, LLC.

“CDM” means Cotton Draw Midstream, L.L.C.

“DD&A” means depreciation, depletion and amortization expenses.

"EPA" means the United States Environmental Protection Agency.

“ESG” means environmental, social and governance.

“G&A” means general and administrative expenses.

“GAAP” means U.S. generally accepted accounting principles.

“Inside FERC” refers to the publication Inside FERC’s Gas Market Report.

"IRA" refers to the Inflation Reduction Act of 2022.

“LOE” means lease operating expenses.

"Matterhorn" refers to Matterhorn Express Pipeline, LLC and, as applicable, its direct parent, MXP Parent, LLC.

“MBbls” means thousand barrels.

“MBoe” means thousand Boe.

“Mcf” means thousand cubic feet.

"Merger" means the merger of East Merger Sub, Inc., a wholly-owned subsidiary of the Company ("Merger Sub") with and into WPX, with WPX continuing as the surviving corporation and a wholly-owned subsidiary of the Company, pursuant to the terms of that certain Agreement and Plan of Merger, dated September 26, 2020, by and among the Company, Merger Sub and WPX.

“MMBoe” means million Boe.

“MMBtu” means million Btu.

“MMcf” means million cubic feet.

“N/M” means not meaningful.

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"NCI" means noncontrolling interests.

“NGL” or “NGLs” means natural gas liquids.

“NYMEX” means New York Mercantile Exchange.

“OPEC” means Organization of the Petroleum Exporting Countries.

“SEC” means United States Securities and Exchange Commission.

“2018 Senior Credit Facility” means Devon’s syndicated unsecured revolving line of credit, effective as of October 5, 2018.

“2023 Senior Credit Facility” means Devon’s syndicated unsecured revolving line of credit, effective as of March 24, 2023.

“TSR” means total shareholder return.

“U.S.” means United States of America.

“VIE” means variable interest entity.

“WPX” means WPX Energy, Inc.

“WTI” means West Texas Intermediate.

“/Bbl” means per barrel.

“/d” means per day.

“/MMBtu” means per MMBtu.

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INFORMATION REGARDING FORWARD-LOOKING STATEMENTS

This report includes “forward-looking statements” as defined by the SEC. Such statements include those concerning strategic plans, our expectations and objectives for future operations, as well as other future events or conditions, and are often identified by use of the words and phrases “expects,” “believes,” “will,” “would,” “could,” “continue,” “may,” “aims,” “likely to be,” “intends,” “forecasts,” “projections,” “estimates,” “plans,” “expectations,” “targets,” “opportunities,” “potential,” “anticipates,” “outlook” and other similar terminology. All statements, other than statements of historical facts, included in this report that address activities, events or developments that Devon expects, believes or anticipates will or may occur in the future are forward-looking statements. Such statements are subject to a number of assumptions, risks and uncertainties, many of which are beyond our control. Consequently, actual future results could differ materially and adversely from our expectations due to a number of factors, including, but not limited to:

•

the volatility of oil, gas and NGL prices;

•

uncertainties inherent in estimating oil, gas and NGL reserves;

•

the extent to which we are successful in acquiring and discovering additional reserves;

•

the uncertainties, costs and risks involved in our operations;

•

risks related to our hedging activities;

•

our limited control over third parties who operate some of our oil and gas properties;

•

midstream capacity constraints and potential interruptions in production, including from limits to the build out of midstream infrastructure;

•

competition for assets, materials, people and capital;

•

regulatory restrictions, compliance costs and other risks relating to governmental regulation, including with respect to federal lands, environmental matters and seismicity;

•

risks related to regulatory, social and market efforts to address climate change;

•

governmental interventions in energy markets;

•

risks relating to the COVID-19 pandemic or other future pandemics;

•

counterparty credit risks;

•

risks relating to our indebtedness;

•

cyberattack risks;

•

the extent to which insurance covers any losses we may experience;

•

risks related to stockholder activism;

•

our ability to successfully complete mergers, acquisitions and divestitures;

•

our ability to pay dividends and make share repurchases; and

•

any of the other risks and uncertainties discussed in this report, our 2022 Annual Report on Form 10-K and our other filings with the SEC.

The forward-looking statements included in this filing speak only as of the date of this report, represent management’s current reasonable expectations as of the date of this filing and are subject to the risks and uncertainties identified above as well as those described elsewhere in this report and in other documents we file from time to time with the SEC. We cannot guarantee the accuracy of our forward-looking statements, and readers are urged to carefully review and consider the various disclosures made in this report and in other documents we file from time to time with the SEC. All subsequent written and oral forward-looking statements attributable to Devon, or persons acting on its behalf, are expressly qualified in their entirety by the cautionary statements above. We do not undertake, and expressly disclaim, any duty to update or revise our forward-looking statements based on new information, future events or otherwise.

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Part I. Financial Information

Item 1. Financial Statements

DEVON ENERGY CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF COMPREHENSIVE EARNINGS


	Three Months Ended March 31,
	2023		2022
	(Unaudited)
Oil, gas and NGL sales	$	2,679	$	3,175
Oil, gas and NGL derivatives		64		(683	)
Marketing and midstream revenues		1,080		1,320
Total revenues		3,823		3,812
Production expenses		693		618
Exploration expenses		3		2
Marketing and midstream expenses		1,105		1,324
Depreciation, depletion and amortization		615		489
Asset dispositions		—		(1	)
General and administrative expenses		106		94
Financing costs, net		72		85
Other, net		5		(61	)
Total expenses		2,599		2,550
Earnings before income taxes		1,224		1,262
Income tax expense		221		267
Net earnings		1,003		995
Net earnings attributable to noncontrolling interests		8		6
Net earnings attributable to Devon	$	995	$	989
Net earnings per share:
Basic net earnings per share	$	1.53	$	1.48
Diluted net earnings per share	$	1.53	$	1.48
Comprehensive earnings:
Net earnings	$	1,003	$	995
Other comprehensive earnings, net of tax:
Pension and postretirement plans		1		1
Other comprehensive earnings, net of tax		1		1
Comprehensive earnings:	$	1,004	$	996
Comprehensive earnings attributable to noncontrolling interests		8		6
Comprehensive earnings attributable to Devon	$	996	$	990

See accompanying notes to consolidated financial statements

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DEVON ENERGY CORPORATION AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS


	March 31, 2023			December 31, 2022
	(Unaudited)
ASSETS
Current assets:
Cash, cash equivalents and restricted cash	$	887		$	1,454
Accounts receivable		1,615			1,767
Inventory		212			201
Other current assets		475			469
Total current assets		3,189			3,891
Oil and gas property and equipment, based on successful efforts accounting, net		16,932			16,567
Other property and equipment, net ($112 million and $109 million related to CDM in 2023 and 2022, respectively)		1,583			1,539
Total property and equipment, net		18,515			18,106
Goodwill		753			753
Right-of-use assets		219			224
Investments		469			440
Other long-term assets		275			307
Total assets	$	23,420		$	23,721
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable	$	935		$	859
Revenues and royalties payable		1,266			1,506
Short-term debt		247			251
Other current liabilities		483			489
Total current liabilities		2,931			3,105
Long-term debt		6,175			6,189
Lease liabilities		256			257
Asset retirement obligations		546			511
Other long-term liabilities		866			900
Deferred income taxes		1,543			1,463
Stockholders' equity:
Common stock, $0.10 par value. Authorized 1.0 billion shares; issued 645 million and 653 million shares in 2023 and 2022, respectively		64			65
Additional paid-in capital		6,344			6,921
Retained earnings		4,712			4,297
Accumulated other comprehensive loss		(115	)		(116	)
Treasury stock, at cost, 0.6 million shares in 2023		(28	)		—
Total stockholders’ equity attributable to Devon		10,977			11,167
Noncontrolling interests		126			129
Total equity		11,103			11,296
Total liabilities and equity	$	23,420		$	23,721

See accompanying notes to consolidated financial statements

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DEVON ENERGY CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS


	Three Months Ended March 31,
	2023			2022
	(Unaudited)
Cash flows from operating activities:
Net earnings	$	1,003		$	995
Adjustments to reconcile net earnings to net cash from operating activities:
Depreciation, depletion and amortization		615			489
Leasehold impairments		—			1
Amortization of liabilities		(7	)		(6	)
Total (gains) losses on commodity derivatives		(64	)		683
Cash settlements on commodity derivatives		13			(344	)
Gains on asset dispositions		—			(1	)
Deferred income tax expense		80			164
Share-based compensation		23			20
Other		2			(21	)
Changes in assets and liabilities, net		12			(143	)
Net cash from operating activities		1,677			1,837
Cash flows from investing activities:
Capital expenditures		(1,012	)		(537	)
Acquisitions of property and equipment		(13	)		(1	)
Divestitures of property and equipment		21			26
Distributions from investments		8			8
Contributions to investments		(37	)		(22	)
Net cash from investing activities		(1,033	)		(526	)
Cash flows from financing activities:
Repurchases of common stock		(517	)		(211	)
Dividends paid on common stock		(596	)		(667	)
Distributions to noncontrolling interests		(11	)		(8	)
Shares exchanged for tax withholdings and other		(87	)		(73	)
Net cash from financing activities		(1,211	)		(959	)
Effect of exchange rate changes on cash		—			2
Net change in cash, cash equivalents and restricted cash		(567	)		354
Cash, cash equivalents and restricted cash at beginning of period		1,454			2,271
Cash, cash equivalents and restricted cash at end of period	$	887		$	2,625

Reconciliation of cash, cash equivalents and restricted cash:
Cash and cash equivalents	$	761		$	2,459
Restricted cash		126			166
Total cash, cash equivalents and restricted cash	$	887		$	2,625

See accompanying notes to consolidated financial statements

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DEVON ENERGY CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF EQUITY


													Other
							Additional						Comprehensive
	Common Stock						Paid-In			Retained			Earnings			Treasury			Noncontrolling			Total
	Shares			Amount			Capital			Earnings			(Loss)			Stock			Interests			Equity
	(Unaudited)
Three Months Ended March 31, 2023
Balance as of December 31, 2022		653		$	65		$	6,921		$	4,297		$	(116	)	$	—		$	129		$	11,296
Net earnings		—			—			—			995			—			—			8			1,003
Other comprehensive earnings, net of tax		—			—			—			—			1			—			—			1
Restricted stock grants, net of cancellations		2			—			—			—			—			—			—			—
Common stock repurchased		—			—			(4	)		—			—			(625	)		—			(629	)
Common stock retired		(11	)		(1	)		(596	)		—			—			597			—			—
Common stock dividends		—			—			—			(580	)		—			—			—			(580	)
Share-based compensation		1			—			23			—			—			—			—			23
Distributions to noncontrolling interests		—			—			—			—			—			—			(11	)		(11	)
Balance as of March 31, 2023		645		$	64		$	6,344		$	4,712		$	(115	)	$	(28	)	$	126		$	11,103
Three Months Ended March 31, 2022
Balance as of December 31, 2021		663		$	66		$	7,636		$	1,692		$	(132	)	$	—		$	137		$	9,399
Net earnings		—			—			—			989			—			—			6			995
Other comprehensive earnings, net of tax		—			—			—			—			1			—			—			1
Restricted stock grants, net of cancellations		2			—			1			—			—			—			—			1
Common stock repurchased		—			—			—			—			—			(305	)		—			(305	)
Common stock retired		(5	)		—			(286	)		—			—			286			—			—
Common stock dividends		—			—			—			(668	)		—			—			—			(668	)
Share-based compensation		1			—			20			—			—			—			—			20
Distributions to noncontrolling interests		—			—			—			—			—			—			(8	)		(8	)
Balance as of March 31, 2022		661		$	66		$	7,371		$	2,013		$	(131	)	$	(19	)	$	135		$	9,435

See accompanying notes to consolidated financial statements

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DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

Summary of Significant Accounting Policies

The accompanying unaudited interim financial statements and notes of Devon have been prepared pursuant to the rules and regulations of the SEC. Pursuant to such rules and regulations, certain disclosures normally included in financial statements prepared in accordance with U.S. GAAP have been omitted. The accompanying unaudited interim financial statements and notes should be read in conjunction with the financial statements and notes included in Devon’s 2022 Annual Report on Form 10-K. The accompanying unaudited interim financial statements in this report reflect all adjustments that are, in the opinion of management, necessary for a fair statement of Devon’s results of operations and cash flows for the three-month periods ended March 31, 2023 and 2022 and Devon’s financial position as of March 31, 2023.

Restricted Cash

As of March 31, 2023, approximately $126 million of cash on the consolidated balance sheets is presented as restricted cash. These obligations primarily relate to an abandoned Canadian firm transportation agreement.

Variable Interest Entity

CDM is a joint venture entity formed by Devon and an affiliate of QL Capital Partners, LP. CDM provides gathering, compression and dehydration services for natural gas production in the Cotton Draw area of the Delaware Basin. Devon holds a controlling interest in CDM and the portions of CDM’s net earnings and equity not attributable to Devon’s controlling interest are shown separately as noncontrolling interests in the accompanying consolidated statements of comprehensive earnings and consolidated balance sheets. CDM is considered a VIE to Devon. The assets of CDM cannot be used by Devon for general corporate purposes and are included in, and disclosed parenthetically, on Devon's consolidated balance sheets. The carrying amount of liabilities related to CDM for which the creditors do not have recourse to Devon's assets are also included in, and disclosed parenthetically, if material, on Devon's consolidated balance sheets.

Investments

The following table presents Devon's investments.


		Carrying Amount
Investments	% Interest	March 31, 2023		December 31, 2022
Catalyst	50%	$	332	$	339
Matterhorn	12.5%		90		54
Other	Various		47		47
Total		$	469	$	440

Devon has an interest in Catalyst, which is a joint venture with an affiliate of Howard Energy Partners, LLC (“HEP”) and certain other investors, to develop oil gathering and natural gas processing infrastructure in the Stateline area of the Delaware Basin. Under the terms of the arrangement, Devon and a holding company owned by the other joint venture investors each have a 50% voting interest in the joint venture legal entity, and HEP serves as the operator. Through 2038, Devon’s production from 50,000 net acres in the Stateline area of the Delaware Basin has been dedicated to Catalyst subject to fixed-fee oil gathering and natural gas processing agreements. Devon accounts for the investment in Catalyst as an equity method investment. Devon's investment in Catalyst is shown within investments on the consolidated balance sheets and Devon's share of Catalyst earnings are reflected as a component of other, net in the accompanying consolidated statements of comprehensive earnings.

During 2023 and 2022, Devon made investments in Matterhorn. Matterhorn is a joint venture entity and was formed for the purpose of constructing a natural gas pipeline that will transport natural gas from the Permian Basin to the Katy, Texas area. Devon's investment in Matterhorn does not give it the ability to exercise significant influence over Matterhorn.

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DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

Disaggregation of Revenue

The following table presents revenue from contracts with customers that are disaggregated based on the type of good or service.


	Three Months Ended March 31,
	2023		2022
Oil	$	2,143	$	2,406
Gas		213		307
NGL		323		462
Oil, gas and NGL sales		2,679		3,175

Oil		730		776
Gas		152		209
NGL		198		335
Marketing and midstream revenues		1,080		1,320
Total revenues from contracts with customers	$	3,759	$	4,495

2. Acquisitions and Divestitures

Acquisitions

In September 2022, Devon completed its acquisition of producing properties and leasehold interests located in the Eagle Ford for cash consideration of approximately $1.7 billion, net of purchase price adjustments. Additionally, in July 2022, Devon completed its acquisition of producing properties and leasehold interests located in the Williston Basin for cash consideration of approximately $830 million, net of purchase price adjustments. The total estimated proved reserves associated with these Eagle Ford and Williston Basin assets is approximately 87 MMBoe and 66 MMBoe, respectively. Each of these acquisitions were accounted for as asset acquisitions as substantially all of the fair value was concentrated in a group of similar assets. Each of the acquisitions resulted in the purchase of producing properties and leasehold interests in a defined geographical and geological area and substantially all of the assets have similar risk characteristics.

Contingent Earnout Payments

Devon is entitled to contingent earnout payments associated with the sale of its Barnett Shale assets in 2020 with upside participation beginning at a $2.75 Henry Hub natural gas price or a $50 WTI oil price. The contingent payment period commenced on January 1, 2021 and has a term of four years. Devon received $65 million in contingent earnout payments related to this transaction in the first quarter of 2023 and 2022 and could receive up to an additional $130 million in contingent earnout payments for the remaining performance periods depending on future commodity prices. The valuation of the future contingent earnout payments included within other current assets and other long-term assets in the March 31, 2023 consolidated balance sheet was approximately $53 million and $35 million, respectively. These values were derived utilizing a Monte Carlo valuation model and qualify as a level 3 fair value measurement.

Devon also received $4 million in contingent earnout payments related to the sale of non-core assets in the Rockies in the first quarter of 2023 and 2022.

Derivative Financial Instruments

Objectives and Strategies

Devon enters into derivative financial instruments with respect to a portion of its oil, gas and NGL production to hedge future prices received. Additionally, Devon periodically enters into derivative financial instruments with respect to a portion of its oil, gas and NGL marketing activities. These commodity derivative financial instruments include financial price swaps, basis swaps and costless price collars.

Devon does not intend to hold or issue derivative financial instruments for speculative trading purposes and has elected not to designate any of its derivative instruments for hedge accounting treatment.

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DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

Counterparty Credit Risk

By using derivative financial instruments, Devon is exposed to credit risk. Credit risk is the failure of the counterparty to perform under the terms of the derivative contract. To mitigate this risk, the hedging instruments are placed with a number of counterparties whom Devon believes are acceptable credit risks. It is Devon’s policy to enter into derivative contracts only with investment-grade rated counterparties deemed by management to be competent and competitive market makers. Additionally, Devon’s derivative contracts generally contain provisions that provide for collateral payments if Devon’s or its counterparty’s credit rating falls below certain credit rating levels. As of March 31, 2023, Devon neither held cash collateral of its counterparties nor posted cash collateral to its counterparties. Given Devon's current credit ratings and the terms of the underlying contracts, Devon is not currently required to post collateral to its counterparties with respect to its open derivative positions, and we would not be required to post any such collateral as a result of any change to the amount of Devon's net liability for such positions.

Commodity Derivatives

As of March 31, 2023, Devon had the following open oil derivative positions. The first table presents Devon’s oil derivatives that settle against the average of the prompt month NYMEX WTI futures price. The second table presents Devon’s oil derivatives that settle against the respective indices noted within the table.


	Price Collars
Period	Volume (Bbls/d)		Weighted Average Floor Price ($/Bbl)		Weighted Average Ceiling Price ($/Bbl)
Q2-Q4 2023		83,329	$	69.48	$	94.66
Q1-Q4 2024		7,486	$	60.00	$	86.17


	Oil Basis Swaps
Period	Index	Volume (Bbls/d)		Weighted Average Differential to WTI ($/Bbl)
Q2-Q4 2023	Midland Sweet		50,091	$	1.09
Q1-Q4 2024	Midland Sweet		48,500	$	1.19
Q1-Q4 2025	Midland Sweet		36,000	$	0.94

As of March 31, 2023, Devon had the following open natural gas derivative positions. The first table presents Devon’s natural gas derivatives that settle against the Inside FERC first of the month Henry Hub index. The second table presents Devon’s natural gas derivatives that settle against the respective indices noted within the table.


	Price Swaps				Price Collars
Period	Volume (MMBtu/d)		Weighted Average Price ($/MMBtu)		Volume (MMBtu/d)		Weighted Average Floor Price ($/MMBtu)		Weighted Average Ceiling Price ($/MMBtu)
Q2-Q4 2023		57,309	$	3.32		187,215	$	3.62	$	7.27
Q1-Q4 2024		40,426	$	3.30		40,527	$	3.78	$	7.05


	Natural Gas Basis Swaps
Period	Index	Volume (MMBtu/d)		Weighted Average Differential to Henry Hub ($/MMBtu)
Q2-Q4 2023	El Paso Natural Gas		141,691	$	(1.58	)
Q2-Q4 2023	Houston Ship Channel		140,000	$	(0.19	)
Q2-Q4 2023	WAHA		70,000	$	(0.51	)
Q1-Q4 2024	El Paso Natural Gas		19,945	$	(0.92	)
Q1-Q4 2024	Houston Ship Channel		30,000	$	(0.32	)
Q1-Q4 2024	WAHA		44,973	$	(0.58	)

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DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

As of March 31, 2023, Devon did not have any open NGL positions.

Financial Statement Presentation

All derivative financial instruments are recognized at their current fair value as either assets or liabilities in the consolidated balance sheets. Amounts related to contracts allowed to be netted upon payment subject to a master netting arrangement with the same counterparty are reported on a net basis in the consolidated balance sheets. The tables below present a summary of these positions as of March 31, 2023 and December 31, 2022.


	March 31, 2023									December 31, 2022
	Gross Fair Value			Amounts Netted			Net Fair Value			Gross Fair Value			Amounts Netted			Net Fair Value			Balance Sheet Classification
Commodity derivatives:
Short-term derivative asset	$	176		$	(5	)	$	171		$	138		$	(19	)	$	119		Other current assets
Long-term derivative asset		14			(3	)		11			12			—			12		Other long-term assets
Short-term derivative liability		(6	)		5			(1	)		(22	)		19			(3	)	Other current liabilities
Long-term derivative liability		(4	)		3			(1	)		—			—			—		Other long-term liabilities
Total derivative asset (liability)	$	180		$	—		$	180		$	128		$	—		$	128

Share-Based Compensation

The table below presents the share-based compensation expense included in Devon’s accompanying consolidated statements of comprehensive earnings.


	Three Months Ended March 31,
	2023		2022
G&A	$	23	$	20
Related income tax benefit	$	20	$	17

Under its approved long-term incentive plan, Devon grants share-based awards to its employees. The following table presents a summary of Devon’s unvested restricted stock awards and units and performance share units granted under the plan.


	Restricted Stock Awards & Units					Performance Share Units
	Awards/Units			Weighted Average Grant-Date Fair Value		Units				Weighted Average Grant-Date Fair Value
	(Thousands, except fair value data)
Unvested at 12/31/22		5,788		$	29.11		1,841			$	31.33
Granted		1,174		$	63.51		743			$	51.38
Vested		(2,378	)	$	25.15		(1,037	)		$	27.89
Forfeited		(32	)	$	42.04		—			$	—
Unvested at 3/31/23		4,552		$	39.95		1,547		(1)	$	43.25

(1)

A maximum of 3.1 million common shares could be awarded based upon Devon’s final TSR ranking.

The following table presents the assumptions related to the performance share units granted in 2023, as indicated in the previous summary table. The grants in the previous summary table also include the impacts of performance share units granted in a prior year that vested higher than 100% of target due to Devon's TSR performance compared to our peers.


	2023
Grant-date fair value	$	81.70
Risk-free interest rate		4.15	%
Volatility factor		61.43	%
Contractual term (years)		2.89

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DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

The following table presents a summary of the unrecognized compensation cost and the related weighted average recognition period associated with unvested awards and units as of March 31, 2023.


	Restricted Stock		Performance
	Awards/Units		Share Units
Unrecognized compensation cost	$	132	$	37
Weighted average period for recognition (years)		3.0		2.0

5. Restructuring

The following table summarizes Devon’s restructuring liabilities. The remaining liabilities primarily relate to an abandoned Canadian firm transportation agreement.


	Other			Other
	Current			Long-term
	Liabilities			Liabilities			Total
Balance as of December 31, 2022	$	34		$	81		$	115
Changes related to prior years' restructurings		(11	)		(3	)		(14	)
Balance as of March 31, 2023	$	23		$	78		$	101

Balance as of December 31, 2021	$	38		$	111		$	149
Changes related to prior years' restructurings		(4	)		(6	)		(10	)
Balance as of March 31, 2022	$	34		$	105		$	139

6. Other, Net

The following table summarizes Devon's other expenses (income) presented in the accompanying consolidated comprehensive statements of earnings.


	Three Months Ended March 31,
	2023			2022
Estimated future obligation under a performance guarantee	$	—		$	(96	)
Ukraine charitable pledge		—			20
Asset retirement obligation accretion		7			7
Other		(2	)		8
Total	$	5		$	(61	)

Devon has guaranteed performance through 2026 for a minimum volume commitment associated with assets divested in 2018. Due to improved commodity prices, market conditions, and performance by the purchaser of the assets, the purchaser was able to fully satisfy the performance obligation due in the first quarter of 2023 and 2022. Additionally, at March 31, 2022, Devon reduced the estimated future exposure of the performance guarantee. The effect of these cash collections and liability revisions resulted in a $96 million benefit in the first quarter of 2022.

The first quarter of 2022 includes a $20 million pledge for humanitarian relief for the Ukrainian people and surrounding countries supporting refugees.

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DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

7. Income Taxes

The following table presents Devon’s total income tax expense and a reconciliation of its effective income tax rate to the U.S. statutory income tax rate.


	Three Months Ended March 31,
	2023			2022
Earnings before income taxes	$	1,224		$	1,262

Current income tax expense	$	141		$	103
Deferred income tax expense		80			164
Total income tax expense	$	221		$	267

U.S. statutory income tax rate		21	%		21	%
State income taxes		1	%		1	%
Other		(4	%)		(1	%)
Effective income tax rate		18	%		21	%

On August 16, 2022 the IRA was signed into law and included various income tax related provisions with effective dates generally beginning in 2023. Among the enacted provisions are a 15% corporate alternative minimum tax ("CAMT") and several new and expanded clean energy credits and incentives. Dependent upon future regulations, Devon believes it is subject to the CAMT as Devon has an average annual adjusted financial statement income that exceeds $1 billion for the three-year period ended December 31, 2022.

In the first quarter of 2023, Devon recognized income tax credits associated with its qualified research activities performed during the 2018 to 2021 tax years. The impact of these credits is included within Other in the table above.

Net Earnings Per Share

The following table reconciles net earnings and weighted-average common shares outstanding used in the calculations of basic and diluted net earnings per share.


	Three Months Ended March 31,
	2023			2022
Net earnings:
Net earnings	$	995		$	989
Attributable to participating securities		(8	)		(16	)
Basic and diluted earnings	$	987		$	973
Common shares:
Common shares outstanding - total		651			663
Attributable to participating securities		(6	)		(7	)
Common shares outstanding - basic		645			656
Dilutive effect of potential common shares issuable		2			2
Common shares outstanding - diluted		647			658
Net earnings per share:
Basic	$	1.53		$	1.48
Diluted	$	1.53		$	1.48

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DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

9. Other Comprehensive Earnings (Loss)

Components of other comprehensive earnings (loss) consist of the following:


	Three Months Ended March 31,
	2023			2022
Pension and postretirement benefit plans:
Beginning accumulated pension and postretirement benefits	$	(116	)	$	(132	)
Recognition of net actuarial loss and prior service cost in earnings (1)		1			1
Accumulated other comprehensive loss, net of tax	$	(115	)	$	(131	)

(1)

Recognition of net actuarial loss and prior service cost are included in the computation of net periodic benefit cost, which is a component of other, net in the accompanying consolidated statements of comprehensive earnings.

10.

Supplemental Information to Statements of Cash Flows


	Three Months Ended March 31,
	2023			2022
Changes in assets and liabilities, net:
Accounts receivable	$	150		$	(457	)
Other current assets		16			64
Other long-term assets		31			66
Accounts payable and revenues and royalties payable		(165	)		247
Other current liabilities		(3	)		8
Other long-term liabilities		(17	)		(71	)
Total	$	12		$	(143	)
Supplementary cash flow data:
Interest paid	$	101		$	100
Income taxes refunded	$	—		$	(23	)

11.

Accounts Receivable

Components of accounts receivable include the following:


	March 31, 2023			December 31, 2022
Oil, gas and NGL sales	$	1,025		$	1,153
Joint interest billings		238			162
Marketing and midstream revenues		325			428
Other		36			33
Gross accounts receivable		1,624			1,776
Allowance for doubtful accounts		(9	)		(9	)
Net accounts receivable	$	1,615		$	1,767

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DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

12. Property, Plant and Equipment

The following table presents the aggregate capitalized costs related to Devon’s oil and gas and non-oil and gas activities.


	March 31, 2023			December 31, 2022
Property and equipment:
Proved	$	43,584		$	42,734
Unproved and properties under development		1,654			1,548
Total oil and gas		45,238			44,282
Less accumulated DD&A		(28,306	)		(27,715	)
Oil and gas property and equipment, net		16,932			16,567
Other property and equipment		2,340			2,280
Less accumulated DD&A		(757	)		(741	)
Other property and equipment, net (1)		1,583			1,539
Property and equipment, net	$	18,515		$	18,106

(1)

$112 million and $109 million related to CDM in 2023 and 2022, respectively.

13.

Debt and Related Expenses

See below for a summary of debt instruments and balances. The notes and debentures are senior, unsecured obligations of Devon.


	March 31, 2023			December 31, 2022
8.25% due August 1, 2023	$	242		$	242
5.25% due September 15, 2024		472			472
5.85% due December 15, 2025		485			485
7.50% due September 15, 2027		73			73
5.25% due October 15, 2027		390			390
5.875% due June 15, 2028		325			325
4.50% due January 15, 2030		585			585
7.875% due September 30, 2031		675			675
7.95% due April 15, 2032		366			366
5.60% due July 15, 2041		1,250			1,250
4.75% due May 15, 2042		750			750
5.00% due June 15, 2045		750			750
Net premium on debentures and notes		92			103
Debt issuance costs		(33	)		(26	)
Total debt	$	6,422		$	6,440
Less amount classified as short-term debt		247			251
Total long-term debt	$	6,175		$	6,189

Credit Lines

On March 24, 2023, Devon amended and restated its 2018 Senior Credit Facility to provide for a new $3.0 billion revolving 2023 Senior Credit Facility with a financial covenant and other terms similar to the 2018 Senior Credit Facility. The 2023 Senior Credit Facility matures on March 24, 2028, with the option to extend the maturity date by three additional one-year periods, subject to lender consent. As of March 31, 2023, Devon had no outstanding borrowings under the 2023 Senior Credit Facility and had issued $2 million in outstanding letters of credit under this facility. The 2023 Senior Credit Facility contains only one material financial covenant. This covenant requires Devon’s ratio of total funded debt to total capitalization, as defined in the credit agreement, to be no greater than 65%. Under the terms of the credit agreement, total capitalization is adjusted to add back non-cash financial write-downs such as impairments. As of March 31, 2023, Devon was in compliance with this covenant with a debt-to-capitalization ratio of 23.2%.

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DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

Net Financing Costs

The following schedule includes the components of net financing costs.


	Three Months Ended March 31,
	2023			2022
Interest based on debt outstanding	$	93		$	92
Interest income		(17	)		(1	)
Other		(4	)		(6	)
Total net financing costs	$	72		$	85

Interest income increased from 2022 to 2023 primarily due to higher interest rates on cash balances.

14. Leases

The following table presents Devon’s right-of-use assets and lease liabilities as of March 31, 2023 and December 31, 2022.


	March 31, 2023						December 31, 2022
	Finance		Operating		Total		Finance		Operating		Total
Right-of-use assets	$	201	$	18	$	219	$	203	$	21	$	224
Lease liabilities:
Current lease liabilities (1)	$	8	$	12	$	20	$	8	$	13	$	21
Long-term lease liabilities		250		6		256		249		8		257
Total lease liabilities	$	258	$	18	$	276	$	257	$	21	$	278

(1) Current lease liabilities are included in other current liabilities on the consolidated balance sheets.

Devon’s right-of-use operating lease assets are for certain leases related to real estate, drilling rigs and other equipment related to the exploration, development and production of oil and gas. Devon’s right-of-use financing lease assets are related to real estate.

15.

Asset Retirement Obligations

The following table presents the changes in Devon’s asset retirement obligations.


	Three Months Ended March 31,
	2023			2022
Asset retirement obligations as of beginning of period	$	529		$	485
Liabilities incurred		6			8
Liabilities settled and divested		(6	)		(3	)
Revision of estimated obligation		27			(35	)
Accretion expense on discounted obligation		7			7
Asset retirement obligations as of end of period		563			462
Less current portion		17			19
Asset retirement obligations, long-term	$	546		$	443

During the first quarter of 2023, Devon increased its asset retirement obligations by approximately $27 million primarily due to inflation-driven increases in current cost estimates. During the first quarter of 2022, Devon reduced its asset retirement obligations by $35 million primarily due to extended retirement dates for oil and gas assets, partially offset by inflation-driven increases to current settlement costs.

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DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

16.

Stockholders’ Equity

Share Repurchases

In November 2021, Devon authorized a share repurchase program of $1.0 billion with a December 31, 2022 expiration date. In 2022, the Board of Directors authorized expansions of the share repurchase program ultimately to $2.0 billion and extended the expiration date to May 4, 2023. In May 2023, the Board of Directors authorized a further expansion to $3.0 billion and extended the expiration date to December 31, 2024. The table below provides information regarding purchases of Devon’s common stock under the $3.0 billion share repurchase program (shares in thousands).


	Total Number of Shares Purchased		Dollar Value of Shares Purchased		Average Price Paid per Share
$3.0 Billion Plan
2021:
Fourth quarter		13,983	$	589	$	42.15
2022:
First quarter		3,979		230	$	57.74
Second quarter		5,052		318	$	63.07
Third quarter		1,875		113	$	59.99
Fourth quarter		802		57	$	71.69
2023:
First quarter		10,090		545	$	53.96
Total plan		35,781	$	1,852	$	51.77

Dividends

Devon pays a quarterly dividend which is comprised of a fixed dividend and a variable dividend. The variable dividend is dependent on quarterly cash flows, among other factors. Devon raised its fixed dividend multiple times over the past year from $0.16 per share in the first quarter of 2022 to $0.20 per share beginning in the first quarter of 2023. The following table summarizes Devon’s fixed and variable dividends for the first quarter of 2023 and 2022, respectively.


	Fixed		Variable		Total		Rate Per Share
2023:
First quarter	$	133	$	463	$	596	$	0.89
2022:
First quarter	$	109	$	558	$	667	$	1.00

In May 2023, Devon announced a cash dividend in the amount of $0.72 per share payable in the second quarter of 2023. The dividend consists of a $0.20 per share fixed quarterly dividend and a $0.52 per share variable quarterly dividend and will total approximately $461 million.

Noncontrolling Interests

The noncontrolling interests’ share of CDM’s net earnings and the contributions from and distributions to the noncontrolling interests are presented as components of equity.

17.

Commitments and Contingencies

Devon is party to various legal actions arising in connection with its business. Matters that are probable of unfavorable outcome to Devon and which can be reasonably estimated are accrued. Such accruals are based on information known about the matters, Devon’s estimates of the outcomes of such matters and its experience in contesting, litigating and settling similar matters. None of the actions are believed by management to likely involve future amounts that would be material to Devon’s financial position or results of operations after consideration of recorded accruals. Actual amounts could differ materially from management’s estimates.

Royalty Matters

Numerous oil and natural gas producers and related parties, including Devon, have been named in various lawsuits alleging royalty underpayments. Devon is currently named as a defendant in a number of such lawsuits, including some lawsuits in which the

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DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

plaintiffs seek to certify classes of similarly situated plaintiffs. Among the allegations typically asserted in these suits are claims that Devon used below-market prices, made improper deductions, paid royalty proceeds in an untimely manner without including required interest, used improper measurement techniques and entered into gas purchase and processing arrangements with affiliates that resulted in underpayment of royalties in connection with oil, natural gas and NGLs produced and sold. Devon is also involved in governmental agency proceedings and royalty audits and is subject to related contracts and regulatory controls in the ordinary course of business, some that may lead to additional royalty claims.

Environmental and Climate Change Matters

Devon’s business is subject to numerous federal, state, tribal and local laws and regulations governing the discharge of materials into the environment or otherwise relating to environmental protection. Failure to comply with these laws and regulations may result in the assessment of administrative, civil and criminal fines and penalties, as well as remediation costs. Although Devon believes that it is in substantial compliance with applicable environmental laws and regulations and that continued compliance with existing requirements will not have a material adverse impact on its business, there can be no assurance that this will continue in the future.

Beginning in 2013, various parishes in Louisiana filed suit against numerous oil and gas companies, including Devon, alleging that the companies’ operations and activities in certain fields violated the State and Local Coastal Resource Management Act of 1978, as amended, and caused substantial environmental contamination, subsidence and other environmental damages to land and water bodies located in the coastal zone of Louisiana. The plaintiffs’ claims against Devon relate primarily to the operations of several of Devon’s corporate predecessors. The plaintiffs seek, among other things, payment of the costs necessary to clear, re-vegetate and otherwise restore the allegedly impacted areas. Although Devon cannot predict the ultimate outcome of these matters, Devon denies the allegations in these lawsuits and intends to vigorously defend against these claims.

The State of Delaware and various municipalities and other governmental and private parties in California have filed legal proceedings against numerous oil and gas companies, including Devon, seeking relief to abate alleged impacts of climate change. These proceedings include far-reaching claims for monetary damages and injunctive relief. Although Devon cannot predict the ultimate outcome of these matters, Devon denies all allegations asserted in these lawsuits and intends to vigorously defend against these claims.

Other Indemnifications and Legacy Matters

Pursuant to various sale agreements relating to divested businesses and assets, Devon has indemnified various purchasers against liabilities that they may incur with respect to the businesses and assets acquired from Devon. Additionally, federal, state and other laws in areas of former operations may require previous operators (including corporate successors of previous operators) to perform or make payments in certain circumstances where the current operator may no longer be able to satisfy the applicable obligation. Such obligations may include plugging and abandoning wells, removing production facilities or performing requirements under surface agreements in existence at the time of disposition.

In November 2020, the Department of the Interior, Bureau of Safety and Environmental Enforcement ordered several oil and gas operators, including Devon, to perform decommissioning and reclamation activities related to two California offshore oil and gas production platforms and related facilities. The current operator and owner of the platforms contends that it does not have the financial ability to perform these obligations and relinquished the related federal lease in October 2020. In response to the apparent insolvency of the current operator, the government has ordered the former operators and alleged former lease record title owners to decommission the platforms and related facilities. The government contends that an alleged corporate predecessor of Devon owned a partial interest in the subject lease and platforms. Although Devon cannot predict the ultimate outcome of this matter, Devon denies any obligation to decommission the subject platforms, has appealed the order, and believes any decommissioning obligation related to the subject platforms should be assumed by others.

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DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

18.

Fair Value Measurements

The following table provides carrying value and fair value measurement information for certain of Devon’s financial assets and liabilities. The carrying values of cash, accounts receivable, other current receivables, accounts payable, other current payables, accrued expenses and lease liabilities included in the accompanying consolidated balance sheets approximated fair value at March 31, 2023 and December 31, 2022, as applicable. Therefore, such financial assets and liabilities are not presented in the following table.


							Fair Value Measurements Using:
	Carrying			Total Fair			Level 1		Level 2			Level 3
	Amount			Value			Inputs		Inputs			Inputs
March 31, 2023 assets (liabilities):
Cash equivalents	$	217		$	217		$	217	$	—		$	—
Commodity derivatives	$	182		$	182		$	—	$	182		$	—
Commodity derivatives	$	(2	)	$	(2	)	$	—	$	(2	)	$	—
Debt	$	(6,422	)	$	(6,278	)	$	—	$	(6,278	)	$	—
Contingent earnout payments	$	88		$	88		$	—	$	—		$	88
December 31, 2022 assets (liabilities):
Cash equivalents	$	708		$	708		$	708	$	—		$	—
Commodity derivatives	$	131		$	131		$	—	$	131		$	—
Commodity derivatives	$	(3	)	$	(3	)	$	—	$	(3	)	$	—
Debt	$	(6,440	)	$	(6,231	)	$	—	$	(6,231	)	$	—
Contingent earnout payments	$	157		$	157		$	—	$	—		$	157

The following methods and assumptions were used to estimate the fair values in the table above.

Level 1 Fair Value Measurements

Cash equivalents – Amounts consist primarily of money market investments and the fair value approximates the carrying value.

Level 2 Fair Value Measurements

Commodity derivatives – The fair value of commodity derivatives is estimated using internal discounted cash flow calculations based upon forward curves and data obtained from independent third parties for contracts with similar terms or data obtained from counterparties to the agreements.

Debt – Devon’s debt instruments do not consistently trade actively in an established market. The fair values of its debt are estimated based on rates available for debt with similar terms and maturity when active trading is not available.

Level 3 Fair Value Measurements

Contingent Earnout Payments – Devon has the right to receive contingent consideration related to the Barnett asset divestiture based on future oil and gas prices. These values were derived using a Monte Carlo valuation model and qualify as a level 3 fair value measurement. For additional information, see Note 2.

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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

The following discussion and analysis addresses material changes in our results of operations for the three-month period ended March 31, 2023 compared to previous periods, and in our financial condition and liquidity since December 31, 2022. For information regarding our critical accounting policies and estimates, see our 2022 Annual Report on Form 10-K under “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.”

Executive Overview

We are a leading independent oil and natural gas exploration and production company whose operations are focused onshore in the United Sates. Our operations are currently focused in five core areas: the Delaware Basin, Eagle Ford, Anadarko Basin, Williston Basin and Powder River Basin. Our asset base is underpinned by premium acreage in the economic core of the Delaware Basin and our diverse, top-tier resource plays provide a deep inventory of opportunities for years to come. In the third quarter of 2022, we acquired additional producing properties and leasehold interests in both the Williston Basin and Eagle Ford that were complementary to our existing acreage, offered operational synergies and added additional high-quality inventory to our portfolio.

We remain focused on building economic value by executing on our strategic priorities of moderating production growth, emphasizing capital and operational efficiencies, optimizing reinvestment rates to maximize free cash flow, maintaining low leverage, delivering cash returns to our shareholders and pursuing ESG excellence. Our recent performance highlights for these priorities include the following items:

•

First quarter oil production totaled 320 MBbls/d, which was an 11% increase from the first quarter of 2022.

•

Expanded our authorized share repurchase program to $3.0 billion in May 2023, and through April 2023 have repurchased approximately 38.5 million of our common shares for $2.0 billion, or $51.91 per share, since inception of the plan.

•

Exited the first quarter with $3.9 billion of liquidity, including $0.9 billion of cash.

•

Generated $1.7 billion of operating cash flow in the first quarter of 2023 and $8.4 billion for the past twelve trailing months.

•

Including variable dividends, paid dividends of approximately $596 million in the first quarter of 2023 and have declared approximately $461 million of dividends to be paid in the second quarter of 2023.

We remain committed to capital discipline and delivering the objectives that underpin our current plan. Those objectives prioritize value creation through moderated capital investment and production growth, particularly with a view of the volatility in commodity prices, supply chain constraints and the economic uncertainty arising from inflation and recent geopolitical events.

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Results of Operations

The following graphs, discussion and analysis are intended to provide an understanding of our results of operations and current financial condition. To facilitate the review, these numbers are being presented before consideration of noncontrolling interests.

Q1 2023 vs. Q4 2022

Our first quarter 2023 and fourth quarter 2022 net earnings were $1.0 billion and $1.2 billion, respectively. The graph below shows the change in net earnings from the fourth quarter of 2022 to the first quarter of 2023. The material changes are further discussed by category on the following pages.

Production Volumes


	Q1 2023		% of Total			Q4 2022		Change
Oil (MBbls/d)
Delaware Basin		211		66	%		201		5	%
Eagle Ford		40		13	%		42		-4	%
Anadarko Basin		15		5	%		15		1	%
Williston Basin		36		11	%		37		-4	%
Powder River Basin		14		4	%		16		-9	%
Other		4		1	%		5		-14	%
Total		320		100	%		316		2	%


	Q1 2023		% of Total			Q4 2022		Change
Gas (MMcf/d)
Delaware Basin		640		62	%		626		2	%
Eagle Ford		82		8	%		84		-3	%
Anadarko Basin		237		23	%		238		0	%
Williston Basin		54		5	%		64		-15	%
Powder River Basin		16		2	%		21		-24	%
Other		1		0	%		1		32	%
Total		1,030		100	%		1,034		0	%


	Q1 2023		% of Total			Q4 2022		Change
NGLs (MBbls/d)
Delaware Basin		97		65	%		101		-4	%
Eagle Ford		15		10	%		12		24	%
Anadarko Basin		26		18	%		23		15	%
Williston Basin		8		6	%		9		-11	%
Powder River Basin		2		1	%		3		-23	%
Other		1		0	%		—	N/M
Total		149		100	%		148		1	%

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	Q1 2023		% of Total			Q4 2022		Change
Combined (MBoe/d)
Delaware Basin		415		65	%		407		2	%
Eagle Ford		68		11	%		68		1	%
Anadarko Basin		81		12	%		77		5	%
Williston Basin		53		8	%		57		-7	%
Powder River Basin		19		3	%		22		-13	%
Other		5		1	%		5		-7	%
Total		641		100	%		636		1	%

From the fourth quarter of 2022 to the first quarter of 2023, the change in volumes contributed to a $31 million decrease to earnings as the higher production per day was offset by fewer days in the first quarter. The increase in volumes per day was primarily due to new well activity in the Delaware and Anadarko Basins which was partially offset by natural declines in the Williston and Powder River Basins.

Realized Prices


	Q1 2023			Realization	Q4 2022			Change
Oil (per Bbl)
WTI index	$	76.17			$	82.53			-8	%
Realized price, unhedged	$	74.32		98%	$	82.31			-10	%
Cash settlements	$	(0.10	)		$	(4.87	)
Realized price, with hedges	$	74.22		97%	$	77.44			-4	%


	Q1 2023		Realization	Q4 2022			Change
Gas (per Mcf)
Henry Hub index	$	3.44		$	6.26			-45	%
Realized price, unhedged	$	2.29	67%	$	4.39			-48	%
Cash settlements	$	0.18		$	(0.38	)
Realized price, with hedges	$	2.47	72%	$	4.01			-38	%


	Q1 2023		Realization	Q4 2022		Change
NGLs (per Bbl)
WTI index	$	76.17		$	82.53		-8	%
Realized price, unhedged	$	24.12	32%	$	24.32		-1	%
Cash settlements	$	—		$	—
Realized price, with hedges	$	24.12	32%	$	24.32		-1	%


	Q1 2023		Q4 2022			Change
Combined (per Boe)
Realized price, unhedged	$	46.44	$	53.66			-13	%
Cash settlements	$	0.22	$	(3.04	)
Realized price, with hedges	$	46.66	$	50.62			-8	%

From the fourth quarter of 2022 to the first quarter of 2023, realized prices contributed to a $429 million decrease in earnings. Unhedged realized oil, gas and NGL prices decreased primarily due to lower WTI, Henry Hub and Mont Belvieu index prices. The decrease in index prices was partially offset by improved hedge cash settlements related to gas commodities.

We currently have approximately 25% of both our remaining anticipated 2023 oil and gas production hedged.

Hedge Settlements


	Q1 2023			Q4 2022			Change
	Q
Oil	$	(3	)	$	(141	)		98	%
Natural gas		16			(36	)		144	%
Total cash settlements (1)	$	13		$	(177	)		107	%

(1)

Included as a component of oil, gas and NGL derivatives on the consolidated statements of comprehensive earnings.

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Cash settlements as presented in the tables above represent realized gains or losses related to the instruments described in Note 3 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

Production Expenses


	Q1 2023			Q4 2022			Change
LOE	$	327		$	308			6	%
Gathering, processing & transportation		166			178			-7	%
Production taxes		175			210			-17	%
Property taxes		25			19			32	%
Total	$	693		$	715			-3	%
Per Boe:
LOE	$	5.67		$	5.26			8	%
Gathering, processing & transportation	$	2.88		$	3.05			-6	%
Percent of oil, gas and NGL sales:
Production taxes		6.5	%		6.7	%		-2	%

Production expenses decreased from the fourth quarter of 2022 to the first quarter of 2023 primarily due to a decrease in production taxes which resulted from lower commodity prices. This decrease in production expenses was partially offset by an increase in LOE.

Field-Level Cash Margin

The table below presents the field-level cash margin for each of our operating areas. Field-level cash margin is computed as oil, gas and NGL sales less production expenses and is not a measure defined by GAAP. A reconciliation to the comparable GAAP measures is found in “Non-GAAP Measures” in this Item 2. The changes in production volumes, realized prices and production expenses, shown above, had the following impact on our field-level cash margins by asset.


	Q1 2023		$ per BOE		Q4 2022		$ per BOE
Field-level cash margin (Non-GAAP)
Delaware Basin	$	1,334	$	35.71	$	1,585	$	42.38
Eagle Ford		257	$	41.75		321	$	51.24
Anadarko Basin		154	$	21.09		203	$	28.53
Williston Basin		156	$	32.65		194	$	37.02
Powder River Basin		70	$	41.43		99	$	49.33
Other		15	N/M			22	N/M
Total	$	1,986	$	34.42	$	2,424	$	41.44

DD&A


	Q1 2023		Q4 2022		Change
Oil and gas per Boe	$	10.25	$	10.14		1	%

Oil and gas	$	591	$	593		0	%
Other property and equipment		24		32		-27	%
Total	$	615	$	625		-2	%

General and Administrative Expense


	Q1 2023		Q4 2022		Change
G&A per Boe	$	1.85	$	2.07		-11	%

Labor and benefits	$	56	$	74		-24	%
Non-labor		50		48		4	%
Total	$	106	$	122		-13	%

G&A decreased in the first quarter of 2023 primarily due to a decrease in labor and benefit costs.

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Other Items


	Q1 2023			Q4 2022			Change in earnings
Commodity hedge valuation changes (1)	$	51		$	124		$	(73	)
Marketing and midstream operations		(25	)		(18	)		(7	)
Exploration expenses		3			13			10
Asset dispositions		—			(29	)		(29	)
Net financing costs		72			73			1
Other, net		5			(4	)		(9	)
							$	(107	)

(1)

Included as a component of oil, gas and NGL derivatives on the consolidated statements of comprehensive earnings.

We recognize fair value changes on our oil, gas and NGL derivative instruments in each reporting period. The changes in fair value resulted from new positions and settlements that occurred during each period, as well as the relationship between contract prices and the associated forward curves. For additional information, see Note 3 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

Asset dispositions include $28 million in the fourth quarter of 2022 related to the re-valuation of contingent earnout payments associated with divested Barnett Shale assets. For additional information, see Note 2 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

Income Taxes


	Q1 2023			Q4 2022
Current expense	$	141		$	84
Deferred expense		80			265
Total expense	$	221		$	349
Current tax rate		12	%		5	%
Deferred tax rate		6	%		17	%
Effective income tax rate		18	%		22	%

For discussion on income taxes, see Note 7 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

Q1 2023 vs. Q1 2022

Our first quarter 2023 and 2022 net earnings were both $1.0 billion. The graph below shows the change in net earnings from the first quarter of 2022 to the first quarter of 2023. The material changes are further discussed by category on the following pages.

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Production Volumes


	Q1 2023		% of Total			Q1 2022		Change
Oil (MBbls/d)
Delaware Basin		211		66	%		209		1	%
Eagle Ford		40		13	%		17		137	%
Anadarko Basin		15		5	%		14		6	%
Williston Basin		36		11	%		32		12	%
Powder River Basin		14		4	%		12		14	%
Other		4		1	%		4		-2	%
Total		320		100	%		288		11	%


	Q1 2023		% of Total			Q1 2022		Change
Gas (MMcf/d)
Delaware Basin		640		62	%		561		14	%
Eagle Ford		82		8	%		61		33	%
Anadarko Basin		237		23	%		210		13	%
Williston Basin		54		5	%		54		0	%
Powder River Basin		16		2	%		19		-14	%
Other		1		0	%		1		37	%
Total		1,030		100	%		906		14	%


	Q1 2023		% of Total			Q1 2022		Change
NGLs (MBbls/d)
Delaware Basin		97		65	%		92		6	%
Eagle Ford		15		10	%		9		69	%
Anadarko Basin		26		18	%		25		3	%
Williston Basin		8		6	%		8		6	%
Powder River Basin		2		1	%		2		-4	%
Other		1		0	%		—	N/M
Total		149		100	%		136		10	%


	Q1 2023		% of Total			Q1 2022		Change
Combined (MBoe/d)
Delaware Basin		415		65	%		394		5	%
Eagle Ford		68		11	%		36		90	%
Anadarko Basin		81		12	%		75		8	%
Williston Basin		53		8	%		48		10	%
Powder River Basin		19		3	%		18		7	%
Other		5		1	%		4		6	%
Total		641		100	%		575		12	%

From the first quarter of 2022 to the first quarter of 2023, the change in volumes contributed to a $359 million increase in earnings. Volumes increased due to acquisitions in the Eagle Ford and Williston Basin that both closed in the third quarter of 2022. Volumes also increased due to continued development of the Delaware Basin and new well activity in the Anadarko Basin.

Realized Prices


	Q1 2023			Realization	Q1 2022			Change
Oil (per Bbl)
WTI index	$	76.17			$	94.45			-19	%
Realized price, unhedged	$	74.32		98%	$	92.94			-20	%
Cash settlements	$	(0.10	)		$	(11.32	)
Realized price, with hedges	$	74.22		97%	$	81.62			-9	%


	Q1 2023		Realization	Q1 2022			Change
Gas (per Mcf)
Henry Hub index	$	3.44		$	4.96			-31	%
Realized price, unhedged	$	2.29	67%	$	3.77			-39	%
Cash settlements	$	0.18		$	(0.62	)
Realized price, with hedges	$	2.47	72%	$	3.15			-22	%

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	Q1 2023		Realization	Q1 2022		Change
NGLs (per Bbl)
WTI index	$	76.17		$	94.45		-19	%
Realized price, unhedged	$	24.12	32%	$	37.76		-36	%
Cash settlements	$	—		$	—
Realized price, with hedges	$	24.12	32%	$	37.76		-36	%


	Q1 2023		Q1 2022			Change
Combined (per Boe)
Realized price, unhedged	$	46.44	$	61.40			-24	%
Cash settlements	$	0.22	$	(6.65	)
Realized price, with hedges	$	46.66	$	54.75			-15	%

From the first quarter of 2022 to the first quarter of 2023, realized prices contributed to an $855 million decrease in earnings. Unhedged realized oil, gas and NGL prices decreased primarily due to lower WTI, Henry Hub and Mont Belvieu index prices. The decrease in index prices was partially offset by improved hedge cash settlements related to gas commodities.

Hedge Settlements


	Q1 2023			Q1 2022			Change
Oil	$	(3	)	$	(293	)		99	%
Natural gas		16			(51	)		131	%
Total cash settlements (1)	$	13		$	(344	)		104	%

(1)

Included as a component of oil, gas and NGL derivatives on the consolidated statements of comprehensive earnings.

Production Expenses


	Q1 2023			Q1 2022			Change
LOE	$	327		$	224			46	%
Gathering, processing & transportation		166			161			3	%
Production taxes		175			214			-18	%
Property taxes		25			19			32	%
Total	$	693		$	618			12	%
Per Boe:
LOE	$	5.67		$	4.33			31	%
Gathering, processing & transportation	$	2.88		$	3.11			-7	%
Percent of oil, gas and NGL sales:
Production taxes		6.5	%		6.7	%		-3	%

LOE expenses and LOE per Boe increased primarily due to acquisitions in the Eagle Ford and Williston Basin and inflation. Production taxes decreased due to lower commodity prices.

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Field-Level Cash Margin


	Q1 2023		$ per BOE		Q1 2022		$ per BOE
Field-level cash margin (Non-GAAP)
Delaware Basin	$	1,334	$	35.71	$	1,877	$	52.99
Eagle Ford		257	$	41.75		158	$	48.92
Anadarko Basin		154	$	21.09		204	$	30.31
Williston Basin		156	$	32.65		207	$	47.65
Powder River Basin		70	$	41.43		86	$	54.32
Other		15	N/M			25	N/M
Total	$	1,986	$	34.42	$	2,557	$	49.45

DD&A


	Q1 2023		Q1 2022		Change
Oil and gas per Boe	$	10.25	$	8.95		14	%

Oil and gas	$	591	$	463		28	%
Other property and equipment		24		26		-9	%
Total	$	615	$	489		26	%

DD&A and our oil and gas per Boe rate both increased primarily due to acquisitions in the Eagle Ford and Williston Basin that closed in the third quarter of 2022.

General and Administrative Expense


	Q1 2023		Q1 2022		Change
G&A per Boe	$	1.85	$	1.82		2	%

Labor and benefits	$	56	$	58		-3	%
Non-labor		50		36		39	%
Total	$	106	$	94		13	%

G&A increased in the first quarter of 2023 primarily due to an increase in non-labor costs.

Other Items


	Q1 2023			Q1 2022			Change in earnings
Commodity hedge valuation changes (1)	$	51		$	(339	)	$	390
Marketing and midstream operations		(25	)		(4	)		(21	)
Exploration expenses		3			2			(1	)
Asset dispositions		—			(1	)		(1	)
Net financing costs		72			85			13
Other, net		5			(61	)		(66	)
							$	314

(1)

Included as a component of oil, gas and NGL derivatives on the consolidated statements of comprehensive earnings.

Net financing costs decreased in the first quarter of 2023 due to an increase in interest income resulting from higher interest rates. For additional information, see Note 13 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

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For discussion on other, net, see Note 6 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

Income Taxes


	Q1 2023			Q1 2022
Current expense	$	141		$	103
Deferred expense		80			164
Total expense	$	221		$	267
Current tax rate		12	%		8	%
Deferred tax rate		6	%		13	%
Effective income tax rate		18	%		21	%

For discussion on income taxes, see Note 7 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

Capital Resources, Uses and Liquidity

Sources and Uses of Cash

The following table presents the major changes in cash and cash equivalents for the three months ended March 31, 2023 and 2022.


	Three Months Ended March 31,
	2023			2022
Operating cash flow	$	1,677		$	1,837
Capital expenditures		(1,012	)		(537	)
Divestitures of property and equipment		21			26
Investment activity, net		(29	)		(14	)
Repurchases of common stock		(517	)		(211	)
Common stock dividends		(596	)		(667	)
Noncontrolling interest activity, net		(11	)		(8	)
Other		(100	)		(72	)
Net change in cash, cash equivalents and restricted cash	$	(567	)	$	354
Cash, cash equivalents and restricted cash at end of period	$	887		$	2,625

Operating Cash Flow

As presented in the table above, net cash provided by operating activities continued to be a significant source of capital and liquidity. Operating cash flow funded all of our capital expenditures and we continued to return value to our shareholders by utilizing cash flow for dividends and share repurchases.

Capital Expenditures

The amounts in the table below reflect cash payments for capital expenditures, including cash paid for capital expenditures incurred in prior periods.


	Three Months Ended March 31,
	2023		2022
Delaware Basin	$	584	$	395
Eagle Ford		192		26
Anadarko Basin		62		10
Williston Basin		99		23
Powder River Basin		38		33
Other		1		3
Total oil and gas		976		490
Midstream		16		29
Other		20		18
Total capital expenditures	$	1,012	$	537

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Capital expenditures consist primarily of amounts related to our oil and gas exploration and development operations, midstream operations and other corporate activities. Our capital investment program is driven by a disciplined allocation process focused on moderating our production growth and maximizing our returns. As such, our capital expenditures for the first quarter of 2023 represent approximately 60% of our operating cash flow. Capital expenditures increased due to capital spend on assets acquired in 2022 and general inflation trends.

Divestitures of Property and Equipment

During the first three months of 2023 and 2022, we received contingent earnout payments related to assets previously sold. For additional information, please see Note 2 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

Investment Activity

During the first three months of both 2023 and 2022, Devon received distributions from our investments of $8 million. Devon contributed $37 million and $22 million to our equity method investments during the first three months of 2023 and 2022, respectively.

Shareholder Distributions and Stock Activity

We repurchased approximately 10.1 million shares of common stock for $545 million and 4.0 million shares of common stock for $230 million under the share repurchase program authorized by our Board of Directors in the first quarter of 2023 and 2022, respectively. For additional information, see Note 16 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

The following table summarizes our common stock dividends during the first quarter of 2023 and 2022. Devon has raised its fixed dividend multiple times over the past year to $0.20 per share in the first quarter of 2023. In addition to the fixed quarterly dividend, we paid a variable dividend in the first quarter of 2023 and 2022.


	Fixed		Variable		Total		Rate Per Share
2023:
First quarter	$	133	$	463	$	596	$	0.89
2022:
First quarter	$	109	$	558	$	667	$	1.00

Noncontrolling Interest Activity, net

During the first three months of 2023 and 2022, we distributed $10 million and $8 million, respectively, to our noncontrolling interests in CDM.

Liquidity

The business of exploring for, developing and producing oil and natural gas is capital intensive. Because oil, natural gas and NGL reserves are a depleting resource, we, like all upstream operators, must continually make capital investments to grow and even sustain production. Generally, our capital investments are focused on drilling and completing new wells and maintaining production from existing wells. At opportunistic times, we also acquire operations and properties from other operators or landowners to enhance our existing portfolio of assets.

Historically, our primary sources of capital funding and liquidity have been our operating cash flow, cash on hand and asset divestiture proceeds. Additionally, we maintain a commercial paper program, supported by our revolving line of credit, which can be accessed as needed to supplement operating cash flow and cash balances. If needed, we can also issue debt and equity securities, including through transactions under our shelf registration statement filed with the SEC. We estimate the combination of our sources of capital will continue to be adequate to fund our planned capital requirements as discussed in this section as well as accelerate our cash-return business model.

Operating Cash Flow

Key inputs into determining our planned capital investment are the amount of cash we hold and operating cash flow we expect to generate over the next one to three or more years. At the end of the first quarter of 2023, we held approximately $0.9 billion of cash. Our operating cash flow forecasts are sensitive to many variables and include a measure of uncertainty as actual results may differ from our expectations.

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Commodity Prices – The most uncertain and volatile variables for our operating cash flow are the prices of the oil, gas and NGLs we produce and sell. Prices are determined primarily by prevailing market conditions. Regional and worldwide economic activity, weather and other highly variable factors influence market conditions for these products. These factors, which are difficult to predict, create volatility in prices and are beyond our control.

To mitigate some of the risk inherent in prices, we utilize various derivative financial instruments to protect a portion of our production against downside price risk. The key terms to our oil, gas and NGL derivative financial instruments as of March 31, 2023 are presented in Note 3 in “Part I. Financial Information – Item 1. Financial Statements” of this report.

Further, when considering the current commodity price environment and our current hedge position, we expect to achieve our capital investment priorities. Additionally, we remain committed to capital discipline and focused on delivering the objectives that underpin our capital plan for 2023. The currently elevated level of cost inflation could erode our cost efficiencies gained over previous years and pressure our margins for the remainder of 2023. Despite this, we expect to continue generating material amounts of free cash flow at current commodity price levels due to our strategy of spending within cash flow.

Operating Expenses – Commodity prices can also affect our operating cash flow through an indirect effect on operating expenses. Significant commodity price decreases can lead to a decrease in drilling and development activities. As a result, the demand and cost for people, services, equipment and materials may also decrease, causing a positive impact on our cash flow as the prices paid for services and equipment decline. However, the inverse is also generally true during periods of rising commodity prices. We expect to mitigate the impact of cost inflation through efficiencies gained from the scale of our operations as well as by leveraging our long-standing relationships with our suppliers.

Credit Losses – Our operating cash flow is also exposed to credit risk in a variety of ways. This includes the credit risk related to customers who purchase our oil, gas and NGL production, the collection of receivables from our joint interest owners for their proportionate share of expenditures made on projects we operate and counterparties to our derivative financial contracts. We utilize a variety of mechanisms to limit our exposure to the credit risks of our customers, partners and counterparties. Such mechanisms include, under certain conditions, requiring letters of credit, prepayments or cash collateral postings.

Credit Availability

As of March 31, 2023, we had approximately $3.0 billion of available borrowing capacity under our 2023 Senior Credit Facility. This credit facility supports our $3.0 billion of short-term credit under our commercial paper program. At March 31, 2023, there were no borrowings under our commercial paper program, and we were in compliance with the Senior Credit Facility’s financial covenant.

Debt Ratings

We receive debt ratings from the major ratings agencies in the U.S. In determining our debt ratings, the agencies consider a number of qualitative and quantitative items including, but not limited to, commodity pricing levels, our liquidity, asset quality, reserve mix, debt levels, cost structure, planned asset sales and the size and scale of our production. Our credit rating from Standard and Poor’s Financial Services is BBB with a stable outlook. Our credit rating from Fitch is BBB+ with a stable outlook. Our credit rating from Moody’s Investor Service is Baa2 with a stable outlook. Any rating downgrades may result in additional letters of credit or cash collateral being posted under certain contractual arrangements.

There are no “rating triggers” in any of our contractual debt obligations that would accelerate scheduled maturities should our debt rating fall below a specified level. However, a downgrade could adversely impact our interest rate on any credit facility borrowings and the ability to economically access debt markets in the future.

Fixed Plus Variable Dividend

We are committed to a “fixed plus variable” dividend strategy. Our Board of Directors will consider a number of factors when setting the quarterly dividend, if any, including a general target of paying out approximately 10% of operating cash flow through the fixed dividend. Our Board of Directors increased our quarterly fixed dividend rate by 11% to $0.20 per share beginning in February 2023. In addition to the fixed quarterly dividend, we may pay a variable dividend of up to 50% of our excess free cash flow, which is a non-GAAP measure. Each quarter’s excess free cash flow is computed as operating cash flow (a GAAP measure) before balance sheet changes, less capital expenditures and the fixed dividend. The declaration and payment of any future dividend, whether fixed or variable, will remain at the full discretion of our Board of Directors and will depend on our financial results, cash requirements, future prospects and other factors deemed relevant by the Board.

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Share Repurchases

In May 2023, our Board of Directors increased our share repurchase program by $1.0 billion to a total authorized amount of $3.0 billion, and extended the expiration date to December 31, 2024. Through April 2023, we had executed $2.0 billion of the authorized program.

Capital Expenditures

Our capital expenditures budget for the remainder of 2023 is expected to range from approximately $2.6 billion to $2.8 billion.

Critical Accounting Estimates

Income Taxes

The amount of income taxes recorded requires interpretations of complex rules and regulations of federal, state, provincial and foreign tax jurisdictions. We recognize current tax expense based on estimated taxable income for the current period and the applicable statutory tax rates. We routinely assess potential uncertain tax positions and, if required, estimate and establish accruals for such amounts. We have recognized deferred tax assets and liabilities for temporary differences, operating losses and other tax carryforwards. We routinely assess our deferred tax assets and reduce such assets by a valuation allowance if we deem it is more likely than not that some portion or all of the deferred tax assets will not be realized.

Further, in the event we were to undergo an “ownership change” (as defined in Section 382 of the Internal Revenue Code of 1986, as amended), our ability to use net operating losses and tax credits generated prior to the ownership change may be limited. Generally, an “ownership change” occurs if one or more shareholders, each of whom owns five percent or more in value of a corporation’s stock, increase their aggregate percentage ownership by more than 50 percent over the lowest percentage of stock owned by those shareholders at any time during the preceding three-year period. Based on currently available information, we do not believe an ownership change has occurred during the first quarter of 2023 for Devon, but the Merger did cause an ownership change for WPX and increased the likelihood Devon could experience an ownership change over the next year.

On August 16, 2022, the IRA was signed into law and included various income tax related provisions with an effective date beginning in 2023. Among the enacted provisions are a 15% CAMT and several new and expanded clean energy credits and incentives. Devon believes it is subject to the CAMT as Devon has an average annual adjusted financial statement income that exceeds $1 billion for the three-year period ended December 31, 2022. Devon continues to assess the potential impact of the CAMT, and material incremental cash tax could be incurred depending on actual operating results as well as future U.S. Treasury guidance.

For additional information regarding our critical accounting policies and estimates, see our 2022 Annual Report on Form 10-K.

Non-GAAP Measures

We utilize “core earnings attributable to Devon” and “core earnings per share attributable to Devon” that are not required by or presented in accordance with GAAP. These non-GAAP measures are not alternatives to GAAP measures and should not be considered in isolation or as a substitute for analysis of our results reported under GAAP. Core earnings attributable to Devon, as well as the per share amount, represent net earnings excluding certain non-cash and other items that are typically excluded by securities analysts in their published estimates of our financial results. Our non-GAAP measures are typically used as a quarterly performance measure. Amounts excluded relate to asset dispositions, deferred tax asset valuation allowance and fair value changes in derivative financial instruments.

We believe these non-GAAP measures facilitate comparisons of our performance to earnings estimates published by securities analysts. We also believe these non-GAAP measures can facilitate comparisons of our performance between periods and to the performance of our peers.

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Below are reconciliations of core earnings and core earnings per share attributable to Devon to comparable GAAP measures.


	Three Months Ended March 31,
	Before Tax			After Tax			After NCI			Per Diluted Share
2023
Earnings attributable to Devon (GAAP)	$	1,224		$	1,003		$	995		$	1.53
Adjustments:
Deferred tax asset valuation allowance		—			(3	)		(3	)		(0.01	)
Fair value changes in financial instruments		(53	)		(40	)		(40	)		(0.06	)
Core earnings attributable to Devon (Non-GAAP)	$	1,171		$	960		$	952		$	1.46
2022
Earnings attributable to Devon (GAAP)	$	1,262		$	995		$	989		$	1.48
Adjustments:
Asset dispositions		(1	)		—			—			—
Deferred tax asset valuation allowance		—			6			6			0.01
Fair value changes in financial instruments		338			260			260			0.39
Core earnings attributable to Devon (Non-GAAP)	$	1,599		$	1,261		$	1,255		$	1.88

EBITDAX and Field-Level Cash Margin

To assess the performance of our assets, we use EBITDAX and Field-Level Cash Margin. We compute EBITDAX as net earnings before income tax expense; financing costs, net; exploration expenses; DD&A; asset impairments; asset disposition gains and losses; non-cash share-based compensation; non-cash valuation changes for derivatives and financial instruments; restructuring and transaction costs; accretion on discounted liabilities; and other items not related to our normal operations. Field-Level Cash Margin is computed as oil, gas and NGL sales less production expenses. Production expenses consist of lease operating, gathering, processing and transportation expenses, as well as production and property taxes.

We exclude financing costs from EBITDAX to assess our operating results without regard to our financing methods or capital structure. Exploration expenses and asset disposition gains and losses are excluded from EBITDAX because they generally are not indicators of operating efficiency for a given reporting period. DD&A and impairments are excluded from EBITDAX because capital expenditures are evaluated at the time capital costs are incurred. We exclude share-based compensation, valuation changes, restructuring and transaction costs, accretion on discounted liabilities and other items from EBITDAX because they are not considered a measure of asset operating performance.

We believe EBITDAX and Field-Level Cash Margin provide information useful in assessing our operating and financial performance across periods. EBITDAX and Field-Level Cash Margin as defined by Devon may not be comparable to similarly titled measures used by other companies and should be considered in conjunction with net earnings from operations.

Below are reconciliations of net earnings to EBITDAX and a further reconciliation to Field-Level Cash Margin.


	Three Months Ended March 31,
	2023			2022
Net earnings (GAAP)	$	1,003		$	995
Financing costs, net		72			85
Income tax expense		221			267
Exploration expenses		3			2
Depreciation, depletion and amortization		615			489
Asset dispositions		—			(1	)
Share-based compensation		23			20
Derivative and financial instrument non-cash valuation changes		(51	)		339
Accretion on discounted liabilities and other		5			(61	)
EBITDAX (Non-GAAP)		1,891			2,135
Marketing and midstream revenues and expenses, net		25			4
Commodity derivative cash settlements		(13	)		344
General and administrative expenses, cash-based		83			74
Field-level cash margin (Non-GAAP)	$	1,986		$	2,557

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Item 3. Quantitative and Qualitative Disclosures About Market Risk

Commodity Price Risk

As of March 31, 2023, we have commodity derivatives that pertain to a portion of our estimated production for the last nine months of 2023, as well as for 2024 and 2025. The key terms to our open oil, gas and NGL derivative financial instruments are presented in Note 3 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

The fair values of our commodity derivatives are largely determined by the forward curves of the relevant price indices. At March 31, 2023, a 10% change in the forward curves associated with our commodity derivative instruments would have changed our net positions by approximately $115 million.

Interest Rate Risk

As of March 31, 2023, we had total debt of $6.4 billion. All of our debt is based on fixed interest rates averaging 5.8%.

Foreign Currency Risk

We had no material foreign currency risk at March 31, 2023.

Item 4. Controls and Procedures

Disclosure Controls and Procedures

We have established disclosure controls and procedures to ensure that material information relating to Devon, including its consolidated subsidiaries, is made known to the officers who certify Devon’s financial reports and to other members of senior management and the Board of Directors.

Based on their evaluation, our principal executive and principal financial officers have concluded that our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934) were effective as of March 31, 2023 to ensure that the information required to be disclosed by Devon in the reports that it files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in the SEC rules and forms.

Changes in Internal Control Over Financial Reporting

There were no changes in our internal control over financial reporting that occurred during our most recent fiscal quarter that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II. Other Information

Item 1. Legal Proceedings

We are involved in various legal proceedings incidental to our business. However, to our knowledge as of the date of this report and subject to the environmental matters noted below and in Part I, Item 3. Legal Proceedings of our 2022 Annual Report on Form 10-K, there were no material pending legal proceedings to which we are a party or to which any of our property is subject. For more information on our legal contingencies, see Note 17 in “Part I. Financial Information – Item 1. Financial Statements” of this report.

On February 1, 2023, we received a notice of violation from the EPA relating to alleged air permit violations by WPX Energy Permian, LLC, a wholly-owned subsidiary of the Company, during 2020 in New Mexico. The Company has been engaging with the EPA to resolve this matter. Although this matter is ongoing and management cannot predict its ultimate outcome, the resolution of this matter may result in a fine or penalty in excess of $300,000.

Please see our 2022 Annual Report on Form 10-K and other SEC filings for additional information.

Item 1A. Risk Factors

There have been no material changes to the information included in Item 1A. “Risk Factors” in our 2022 Annual Report on Form 10-K.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

The following table provides information regarding purchases of our common stock that were made by us during the first quarter of 2023 (shares in thousands).


Period	Total Number of Shares Purchased (1)		Average Price Paid per Share		Total Number of Shares Purchased As Part of Publicly Announced Plans or Programs (2)		Maximum Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs (2)
January 1 - January 31		161	$	64.92		158	$	682
February 1 - February 28		4,671	$	55.97		3,743	$	479
March 1 - March 31		6,584	$	53.68		6,189	$	147
Total		11,416	$	54.77		10,090

(1)

In addition to shares purchased under the share repurchase program described below, these amounts also include approximately 1.3 million shares received by us from employees for the payment of personal income tax withholdings on vesting transactions.

(2)

On November 2, 2021, we announced a $1.0 billion share repurchase program with an expiration date of December 31, 2022. In 2022, we announced expansions of this program ultimately to $2.0 billion and extended the expiration date to May 4, 2023. In May 2023, we announced a further expansion to $3.0 billion and extended the expiration date to December 31, 2024. In the first quarter of 2023, we repurchased 10.1 million common shares for $545 million, or $53.96 per share, under this share repurchase program. For additional information, see Note 16 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

Item 3. Defaults Upon Senior Securities

Not applicable.

Item 4. Mine Safety Disclosures

Not applicable.

Item 5. Other Information

Not applicable.

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Item 6. Exhibits


Exhibit Number		Description

10.1	Amended and Restated Credit Agreement, dated March 24, 2023, among Devon Energy Corporation, as borrower, each lender from time to time party thereto, each letter of credit issuer from time to time party thereto, and Bank of America, N.A., as administrative agent and swing line lender (incorporated by reference to Exhibit 10.1 of Registrant’s Form 8-K filed March 28, 2023; File No. 001-32318).

10.2*	2023 Form of Notice of Grant of Restricted Stock Award and Award Agreement under the 2022 Long-Term Incentive Plan between Devon Energy Corporation and certain officers for restricted stock awarded.

10.3*	2023 Form of Notice of Grant of Performance Share Unit Award and Award Agreement under the 2022 Long-Term Incentive Plan between Devon Energy Corporation and certain officers for performance based restricted share units awarded.

31.1	Certification of principal executive officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

31.2	Certification of principal financial officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.

32.1	Certification of principal executive officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

32.2	Certification of principal financial officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

101.INS	Inline XBRL Instance Document – the XBRL Instance Document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.

101.SCH	Inline XBRL Taxonomy Extension Schema Document.

101.CAL	Inline XBRL Taxonomy Extension Calculation Linkbase Document.

101.DEF	Inline XBRL Taxonomy Extension Definition Linkbase Document.

101.LAB	Inline XBRL Taxonomy Extension Labels Linkbase Document.

101.PRE	Inline XBRL Taxonomy Extension Presentation Linkbase Document.

104	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).

*	Indicates management contract or compensatory plan or arrangement.

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.


				DEVON ENERGY CORPORATION

Date: May 9, 2023				/s/ Jeremy D. Humphers
				Jeremy D. Humphers
				Senior Vice President and Chief Accounting Officer