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

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.

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~~July 21, 2021, ~~676.9~~677.0 million shares of common stock were outstanding.

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:

“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.

“Canada” means the division of Devon encompassing oil and gas properties located in Canada. On June 27, 2019, all of Devon’s Canadian operating assets and operations were divested. All dollar amounts associated with Canada are in U.S. dollars, unless stated otherwise.

“~~Federal Funds Rate”~~EPA” means the ~~interest rate at which depository institutions lend balances at the Federal Reserve to other depository institutions overnight.~~United States Environmental Protection Agency.

“Merger” means the merger of 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 the Merger Agreement.

“Merger Agreement” means that certain Agreement and Plan of Merger, dated September 26, 2020, by and among the Company, Merger Sub and WPX.

“Merger Sub” means East Merger Sub, Inc., a wholly-owned subsidiary of the Company.

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

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:

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 assume no duty to update or revise our forward-looking statements based on new information, future events or otherwise.

	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
	2021			2020			2021			2020			2021			2020
	(Unaudited)						(Unaudited)
Oil, gas and NGL sales	$	1,788		$	807		$	2,154		$	424		$	3,911		$	1,231
Oil, gas and NGL derivatives		(528	)		720			(703	)		(361	)		(1,231	)		359
Marketing and midstream revenues		502			560			966			331			1,787			891
Total revenues		1,762			2,087			2,417			394			4,467			2,481
Production expenses		489			318			513			263			971			581
Exploration expenses		3			112			3			12			6			124
Marketing and midstream expenses		523			578			965			339			1,807			917
Depreciation, depletion and amortization		467			401			536			299			1,003			700
Asset impairments		—			2,666			—			—			—			2,666
Asset dispositions		(32	)		—			(87	)		—			(119	)		—
General and administrative expenses		107			102			94			79			201			181
Financing costs, net		77			65			80			69			157			134
Restructuring and transaction costs		189			—			23			—			212			—
Other, net		(29	)		(48	)		(14	)		13			(43	)		(35	)
Total expenses		1,794			4,194			2,113			1,074			4,195			5,268
Loss from continuing operations before income taxes		(32	)		(2,107	)
Income tax benefit		(248	)		(417	)
Earnings (loss) from continuing operations before income taxes								304			(680	)		272			(2,787	)
Income tax expense (benefit)								43			(3	)		(205	)		(420	)
Net earnings (loss) from continuing operations		216			(1,690	)		261			(677	)		477			(2,367	)
Net loss from discontinued operations, net of income taxes		—			(125	)
Net earnings (loss) from discontinued operations, net of income taxes								—			9			—			(116	)
Net earnings (loss)		216			(1,815	)		261			(668	)		477			(2,483	)
Net earnings attributable to noncontrolling interests		3			1			5			2			8			3
Net earnings (loss) attributable to Devon	$	213		$	(1,816	)	$	256		$	(670	)	$	469		$	(2,486	)
Basic net earnings (loss) per share:
Basic earnings (loss) from continuing operations per share	$	0.33		$	(4.48	)	$	0.38		$	(1.80	)	$	0.70		$	(6.29	)
Basic loss from discontinued operations per share		—			(0.34	)
Basic earnings (loss) from discontinued operations per share								—			0.02			—			(0.31	)
Basic net earnings (loss) per share	$	0.33		$	(4.82	)	$	0.38		$	(1.78	)	$	0.70		$	(6.60	)
Diluted net earnings (loss) per share:
Diluted earnings (loss) from continuing operations per share	$	0.32		$	(4.48	)	$	0.38		$	(1.80	)	$	0.70		$	(6.29	)
Diluted loss from discontinued operations per share		—			(0.34	)
Diluted earnings (loss) from discontinued operations per share								—			0.02			—			(0.31	)
Diluted net earnings (loss) per share	$	0.32		$	(4.82	)	$	0.38		$	(1.78	)	$	0.70		$	(6.60	)
Comprehensive earnings (loss):
Net earnings (loss)	$	216		$	(1,815	)	$	261		$	(668	)	$	477		$	(2,483	)
Other comprehensive earnings (loss), net of tax:
Pension and postretirement plans		23			1			3			1			26			2
Other comprehensive earnings, net of tax		23			1			3			1			26			2
Comprehensive earnings (loss):	$	239		$	(1,814	)	$	264		$	(667	)	$	503		$	(2,481	)
Comprehensive earnings attributable to noncontrolling interests		3			1			5			2			8			3
Comprehensive earnings (loss) attributable to Devon	$	236		$	(1,815	)	$	259		$	(669	)	$	495		$	(2,484	)

	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
	2021			2020			2021			2020			2021			2020
	(Unaudited)						(Unaudited)
Cash flows from operating activities:
Net earnings (loss)	$	216		$	(1,815	)	$	261		$	(668	)	$	477		$	(2,483	)
Adjustments to reconcile net earnings (loss) to net cash from operating activities:
Net loss from discontinued operations, net of income taxes		—			125
Net (earnings) loss from discontinued operations, net of income taxes								—			(9	)		—			116
Depreciation, depletion and amortization		467			401			536			299			1,003			700
Asset impairments		—			2,666			—			—			—			2,666
Leasehold impairments		1			110			1			3			2			113
(Amortization) accretion of liabilities		(54	)		8			(7	)		8			(14	)		16
Total (gains) losses on commodity derivatives		528			(720	)		703			361			1,231			(359	)
Cash settlements on commodity derivatives		(232	)		101			(367	)		232			(599	)		333
Gains on asset dispositions		(32	)		—			(87	)		—			(119	)		—
Deferred income tax benefit		(243	)		(311	)
Deferred income tax expense (benefit)								24			—			(219	)		(311	)
Share-based compensation		41			20			20			19			61			39
Early retirement of debt		27			—			(10	)		—			(30	)		—
Other								2			4			2			4
Changes in assets and liabilities, net		(127	)		(56	)		17			(99	)		(110	)		(155	)
Net cash from operating activities - continuing operations		592			529			1,093			150			1,685			679
Cash flows from investing activities:
Capital expenditures		(499	)		(425	)		(504	)		(307	)		(1,003	)		(732	)
Acquisitions of property and equipment		—			(4	)		(5	)		(1	)		(5	)		(5	)
Divestitures of property and equipment		15			25			49			3			64			28
WPX acquired cash		344			—			—			—			344			—
Distributions from equity method investments		10			—			8			—			18			—
Net cash from investing activities - continuing operations		(130	)		(404	)		(452	)		(305	)		(582	)		(709	)
Cash flows from financing activities:
Repayments of long-term debt		(533	)		—			(710	)		—			(1,243	)		—
Early retirement of debt		(27	)		—			(32	)		—			(59	)		—
Repurchases of common stock		—			(38	)		—			—			—			(38	)
Dividends paid on common stock		(203	)		(34	)		(229	)		(42	)		(432	)		(76	)
Contributions from noncontrolling interests		—			5			3			6			3			11
Distributions to noncontrolling interests		(4	)		(3	)		(5	)		(3	)		(9	)		(6	)
Acquisition of noncontrolling interests		(24	)		—			—			—			(24	)		—
Shares exchanged for tax withholdings		(33	)		(17	)
Shares exchanged for tax withholdings and other								(9	)		—			(42	)		(17	)
Net cash from financing activities - continuing operations		(824	)		(87	)		(982	)		(39	)		(1,806	)		(126	)
Effect of exchange rate changes on cash - continuing operations		3			—			2			—			5			—
Net change in cash, cash equivalents and restricted cash of continuing operations		(359	)		38			(339	)		(194	)		(698	)		(156	)
Cash flows from discontinued operations:
Operating activities		0			(131	)		0			(43	)		0			(174	)
Investing activities		0			(1	)		0			171			0			170
Financing activities		0			0			0			0			0			0
Effect of exchange rate changes on cash		0			(23	)		0			8			0			(15	)
Net change in cash, cash equivalents and restricted cash of discontinued operations		0			(155	)		0			136			0			(19	)
Net change in cash, cash equivalents and restricted cash		(359	)		(117	)		(339	)		(58	)		(698	)		(175	)
Cash, cash equivalents and restricted cash at beginning of period		2,237			1,844			1,878			1,727			2,237			1,844
Cash, cash equivalents and restricted cash at end of period	$	1,878		$	1,727		$	1,539		$	1,669		$	1,539		$	1,669

Reconciliation of cash, cash equivalents and restricted cash:
Cash and cash equivalents	$	1,683		$	1,527		$	1,348		$	1,474		$	1,348		$	1,474
Restricted cash		195			200			191			195			191			195
Total cash, cash equivalents and restricted cash	$	1,878		$	1,727		$	1,539		$	1,669		$	1,539		$	1,669

	March 31, 2021			December 31, 2020			June 30, 2021			December 31, 2020
	(Unaudited)						(Unaudited)
ASSETS
Current assets:
Cash, cash equivalents and restricted cash	$	1,878		$	2,237		$	1,539		$	2,237
Accounts receivable		1,089			601			1,185			601
Income taxes receivable		166			174			40			174
Other current assets		334			248			312			248
Total current assets		3,467			3,260			3,076			3,260
Oil and gas property and equipment, based on successful efforts accounting, net		13,826			4,436			13,727			4,436
Other property and equipment, net ($106 million and $102 million related to CDM in 2021 and 2020, respectively)		1,448			957			1,462			957
Total property and equipment, net		15,274			5,393			15,189			5,393
Goodwill		753			753			753			753
Right-of-use assets		255			223			252			223
Investments		402			12			398			12
Other long-term assets		306			271			397			271
Total assets	$	20,457		$	9,912		$	20,065		$	9,912
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable	$	564		$	242		$	487		$	242
Revenues and royalties payable		909			662			1,030			662
Short-term debt		226			—
Other current liabilities		1,246			536			1,555			536
Total current liabilities		2,945			1,440			3,072			1,440
Long-term debt		7,042			4,298			6,502			4,298
Lease liabilities		260			246			258			246
Asset retirement obligations		455			358			450			358
Other long-term liabilities		1,269			551			1,248			551
Stockholders' equity:
Common stock, $0.10 par value. Authorized 1.0 billion shares; issued 675 million and 382 million shares in 2021 and 2020, respectively		67			38
Common stock, $0.10 par value. Authorized 1.0 billion shares; issued 677 million and 382 million shares in 2021 and 2020, respectively								68			38
Additional paid-in capital		8,172			2,766			8,189			2,766
Retained earnings		218			208			243			208
Accumulated other comprehensive loss		(104	)		(127	)		(101	)		(127	)
Total stockholders’ equity attributable to Devon		8,353			2,885			8,399			2,885
Noncontrolling interests		133			134			136			134
Total equity		8,486			3,019			8,535			3,019
Total liabilities and equity	$	20,457		$	9,912		$	20,065		$	9,912

									Retained			Other																							Other
						Additional			Earnings			Comprehensive																	Additional						Comprehensive
	Common Stock					Paid-In			(Accumulated			Earnings			Treasury			Noncontrolling			Total			Common Stock					Paid-In			Retained			Earnings			Treasury			Noncontrolling			Total
	Shares			Amount		Capital			Deficit)			(Loss)			Stock			Interests			Equity			Shares			Amount		Capital			Earnings			(Loss)			Stock			Interests			Equity
	(Unaudited)																							(Unaudited)
Three Months Ended March 31, 2021
Three Months Ended June 30, 2021
Balance as of March 31, 2021																									675		$	67	$	8,172		$	218		$	(104	)	$	—		$	133		$	8,486
Net earnings																									—			—		—			256			—			—			5			261
Other comprehensive earnings, net of tax																									—			—		—			—			3			—			—			3
Restricted stock grants, net of cancellations																									2			1		(1	)		—			—			—			—			—
Common stock repurchased																									—			—		—			—			—			(2	)		—			(2	)
Common stock retired																									—			—		(2	)		—			—			2			—			—
Common stock dividends																									—			—		—			(231	)		—			—			—			(231	)
Share-based compensation																									—			—		20			—			—			—			—			20
Contributions from noncontrolling interests																									—			—		—			—			—			—			2			2
Distributions to noncontrolling interests																									—			—		—			—			—			—			(4	)		(4	)
Balance as of June 30, 2021																									677		$	68	$	8,189		$	243		$	(101	)	$	—		$	136		$	8,535
Three Months Ended June 30, 2020
Balance as of March 31, 2020																									383		$	38	$	2,701		$	1,298		$	(118	)	$	—		$	121		$	4,040
Net earnings (loss)																									—			—		—			(670	)		—			—			2			(668	)
Other comprehensive earnings, net of tax																									—			—		—			—			1			—			—			1
Common stock dividends																									—			—		—			(42	)		—			—			—			(42	)
Share-based compensation																									—			—		19			—			—			—			—			19
Contributions from noncontrolling interests																									—			—		—			—			—			—			6			6
Distributions to noncontrolling interests																									—			—		—			—			—			—			(3	)		(3	)
Balance as of June 30, 2020																									383		$	38	$	2,720		$	586		$	(117	)	$	—		$	126		$	3,353
Six Months Ended June 30, 2021
Balance as of December 31, 2020		382		$	38	$	2,766		$	208		$	(127	)	$	—		$	134		$	3,019			382		$	38	$	2,766		$	208		$	(127	)	$	—		$	134		$	3,019
Net earnings		—			—		—			213			—			—			3			216			—			—		—			469			—			—			8			477
Other comprehensive earnings, net of tax		—			—		—			—			23			—			—			23			—			—		—			—			26			—			—			26
Restricted stock grants, net of cancellations		4			—		—			—			—			—			—			—			6			1		(1	)		—			—			—			—			—
Common stock repurchased		—			—		—			—			—			(38	)		—			(38	)		—			—		—			—			—			(40	)		—			(40	)
Common stock retired		(2	)		—		(38	)		—			—			38			—			—			(2	)		—		(40	)		—			—			40			—			—
Common stock dividends		—			—		—			(203	)		—			—			—			(203	)		—			—		—			(434	)		—			—			—			(434	)
Common stock issued		290			29		5,403			—			—			—			—			5,432			290			29		5,403			—			—			—			—			5,432
Share-based compensation		1			—		41			—			—			—			—			41			1			—		61			—			—			—			—			61
Contributions from noncontrolling interests		—			—		—			—			—			—			—			—			—			—		—			—			—			—			2			2
Distributions to noncontrolling interests		—			—		—			—			—			—			(4	)		(4	)		—			—		—			—			—			—			(8	)		(8	)
Balance as of March 31, 2021		675		$	67	$	8,172		$	218		$	(104	)	$	—		$	133		$	8,486
Three Months Ended March 31, 2020
Balance as of June 30, 2021																									677		$	68	$	8,189		$	243		$	(101	)	$	—		$	136		$	8,535
Six Months Ended June 30, 2020
Balance as of December 31, 2019		382		$	38	$	2,735		$	3,148		$	(119	)	$	—		$	118		$	5,920			382		$	38	$	2,735		$	3,148		$	(119	)	$	—		$	118		$	5,920
Net earnings (loss)		—			—		—			(1,816	)		—			—			1			(1,815	)		—			—		—			(2,486	)		—			—			3			(2,483	)
Other comprehensive earnings, net of tax		—			—		—			—			1			—			—			1			—			—		—			—			2			—			—			2
Restricted stock grants, net of cancellations		3			—		—			—			—			—			—			—			3			—		—			—			—			—			—			—
Common stock repurchased		—			—		—			—			—			(54	)		—			(54	)		—			—		—			—			—			(54	)		—			(54	)
Common stock retired		(3	)		—		(54	)		—			—			54			—			—			(3	)		—		(54	)		—			—			54			—			—
Common stock dividends		—			—		—			(34	)		—			—			—			(34	)		—			—		—			(76	)		—			—			—			(76	)
Share-based compensation		1			—		20			—			—			—			—			20			1			—		39			—			—			—			—			39
Contributions from noncontrolling interests		—			—		—			—			—			—			5			5			—			—		—			—			—			—			11			11
Distributions to noncontrolling interests		—			—		—			—			—			—			(3	)		(3	)		—			—		—			—			—			—			(6	)		(6	)
Balance as of March 31, 2020		383		$	38	$	2,701		$	1,298		$	(118	)	$	—		$	121		$	4,040
Balance as of June 30, 2020																									383		$	38	$	2,720		$	586		$	(117	)	$	—		$	126		$	3,353

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 2020 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 and six-month periods ended ~~March 31,~~June 30, 2021 and 2020 and Devon’s financial position as of ~~March 31,~~June 30, 2021. Certain prior period amounts have been reclassified to conform to the current period’s presentation.

Devon and WPX completed an all-stock merger of equals on January 7, 2021. On the closing date of the Merger, each share of WPX common stock was automatically converted into the right to receive 0.5165 of a share of Devon common stock. The transaction has been accounted for using the acquisition method of accounting, with Devon being treated as the accounting acquirer. See Note 2 for further discussion.

As further discussed in Note 18, Devon closed on the sale of its Barnett Shale assets in October 2020. Prior to December 31, 2020, activity relating to Devon’s Barnett Shale assets is classified as discontinued operations within Devon’s consolidated statements of comprehensive earnings and consolidated statements of cash flows.

As of ~~March 31,~~June 30, 2021, Devon classified approximately ~~$185~~$180 million of cash as restricted cash on the consolidated balance sheets for obligations associated with the abandonment of certain gas processing contracts related to divestitures of ~~other~~our Barnett Shale assets that occurred in 2018 and obligations retained related to the Canadian business. Cash payments for these charges related to the Barnett assets and Canada business total approximately $10 million per quarter.

Cotton Draw Midstream, L.L.C. (“CDM”) is a ~~joint-venture~~joint venture entity formed by Devon and an affiliate of QL Capital Partners, LP (“QLCP”). 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, on Devon's consolidated balance sheets if material.

In conjunction with the Merger, Devon acquired an interest in Catalyst which is a joint venture established between WPX and Howard Energy Partners (“HEP”) to develop oil gathering and natural gas processing infrastructure in the Stateline area of the Delaware Basin. Under the terms of the agreement, Devon and HEP each have a 50 percent 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. The agreements do not include any minimum volume commitments. 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 sheet and Devon’s share of Catalyst earnings are reflected as a component of other, net in the accompanying consolidated statements of comprehensive earnings.

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,				Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020		2021		2020
Oil	$	1,357	$	662	$	1,686	$	296	$	3,017	$	958
Gas		207		70		188		72		390		142
NGL		224		75		280		56		504		131
Oil, gas and NGL sales		1,788		807		2,154		424		3,911		1,231

Oil		209		329		610		140		1,109		469
Gas		118		94		134		81		281		175
NGL		175		137		222		110		397		247
Marketing and midstream revenues		502		560		966		331		1,787		891
Total revenues from contracts with customers	$	2,290	$	1,367	$	3,120	$	755	$	5,698	$	2,122

On January 7, 2021, Devon and WPX completed an all-stock merger of equals. WPX was an oil and gas exploration and production company with assets in the Delaware Basin in Texas and New Mexico and the Williston Basin in North Dakota. On the closing date of the Merger, each share of WPX common stock was automatically converted into the right to receive 0.5165 of a share of Devon common stock. No fractional shares of Devon’s common stock were issued in the Merger, and holders of WPX common stock instead received cash in lieu of fractional shares of Devon common stock, if any. Based on the closing price of Devon’s common stock on January 7, 2021, the total value of Devon common stock issued to holders of WPX common stock as part of this transaction was approximately $5.4 billion. The Merger was structured as a tax-free reorganization for United States federal income tax purposes.

The transaction has been accounted for using the acquisition method of accounting, with Devon being treated as the accounting acquirer. Under the acquisition method of accounting, the assets and liabilities of WPX and its subsidiaries have been recorded at their respective fair values as of the date of completion of the Merger and added to Devon’s. The preliminary purchase price assessment remains an ongoing process and is subject to change for up to one year subsequent to the closing date of the Merger. Determining the fair value of the assets and liabilities of WPX requires judgment and certain assumptions to be made, the most significant of these being related to the valuation of WPX’s oil and gas properties. The inputs and assumptions related to the oil and gas properties are categorized as level 3 in the fair value hierarchy.

The following table represents the preliminary allocation of the total purchase price of WPX to the identifiable assets acquired and the liabilities assumed based on the fair values as of the acquisition date.

			Preliminary Purchase
			Price Allocation
	Preliminary Purchase Price Allocation		as of June 30, 2021
Consideration:
WPX Common Stock outstanding		561.2		561.2
Exchange Ratio		0.5165		0.5165
Devon common stock issued		289.9		289.9
Devon closing price on January 7, 2021	$	18.57	$	18.57
Total common equity consideration		5,383		5,383
Share-based replacement awards		49		49
Total consideration	$	5,432	$	5,432
Assets acquired:
Cash, cash equivalents and restricted cash	$	344	$	344
Accounts receivable		425		425
Other current assets		49		49
Right-of-use assets		38		38
Proved oil and gas property and equipment		7,017		7,017
Unproved and properties under development		2,367		2,367
Other property and equipment		485		485
Investments		400		400
Other long-term assets		43		43
Total assets acquired	$	11,168	$	11,168
Liabilities assumed:
Accounts payable	$	346	$	346
Revenue and royalties payable		223		223
Other current liabilities		454		454
Debt		3,562		3,562
Lease liabilities		38		38
Asset retirement obligations		94		94
Deferred income taxes		254		254
Other long-term liabilities		765		765
Total liabilities assumed		5,736		5,736
Net assets acquired	$	5,432	$	5,432

The following table represents WPX’s revenues and earnings included in Devon’s consolidated ~~comprehensive~~ statements of comprehensive earnings subsequent to the closing date of the Merger.

	Three Months Ended March 31,		Three Months Ended June 30,		Six Months Ended June 30,
	2021		2021		2021
Total revenues	$	772	$	1,353	$	2,413
Net earnings	$	166	$	389	$	555

Due to the Merger closing on January 7, 2021, all activity in the first ~~quarter~~and second quarters of 2021 except for the first six days of January is included in Devon’s consolidated statements of comprehensive ~~earnings.~~earnings for the six months ended June 30, 2021. The following unaudited pro forma financial information for the three and six months ended ~~March 31,~~June 30, 2020 is based on our historical consolidated financial statements adjusted to reflect as if the Merger had occurred on January 1, 2020. The information below reflects pro forma adjustments to conform WPX’s historical financial information to Devon’s financial statement presentation. The unaudited pro forma financial information is not necessarily indicative of what would have occurred if the Merger had been completed as of the beginning of the periods presented, nor is it indicative of future results.

	Three Months Ended March 31,			Three Months Ended June 30,			Six Months Ended June 30,
Continuing operations:	2020			2020			2020
Total revenues	$	3,485		$	427		$	3,912
Net loss	$	(1,864	)	$	(1,102	)	$	(2,966	)
Basic net loss per share	$	(2.77	)	$	(1.65	)	$	(4.45	)

~~On March 3,~~In the first quarter of 2021, Devon completed the sale of non-core assets in the Rockies for proceeds of $9 million, net of purchase price adjustments, and recognized a $35 million gain related to the sale. The transaction includes contingent earnout payments of up to $8 million. The total estimated proved reserves associated with these divested assets ~~are~~was approximately 3 MMBoe. As of December 31, 2020, the associated assets and liabilities were classified as assets held for sale and included in other current assets and other current liabilities, respectively.

~~On October 1,~~In the fourth quarter of 2020, Devon completed the sale of its Barnett Shale assets to BKV for proceeds, net of purchase price adjustments, of $490 million. The agreement with BKV also provides for contingent earnout payments to Devon of up to $260 million based upon future commodity prices, 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 recognized a $748 million asset impairment related to these~~The valuation of the future contingent earnout payments included within other current assets and other long-term assets in the ~~fourth~~June 30, 2021 consolidated balance sheet was $46 million and $85 million, respectively. During the second quarter of ~~2019~~2021, Devon recorded a $65 million increase to the fair value within asset dispositions on the consolidated statements of comprehensive earnings. The value was derived utilizing a Monte Carlo valuation model and ~~incremental asset impairments of $179 million and $3 million during the first quarter and third quarter of 2020, respectively.~~qualifies as a level 3 fair value measurement. Additional information can be found in Note 18.

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, price swaptions, basis swaps, costless price collars and call options. Devon periodically enters into interest rate swaps to manage its exposure to interest rate volatility. As of ~~March 31,~~June 30, 2021, Devon did not have any open interest rate swap contracts.

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.

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,~~June 30, 2021, Devon neither held cash collateral of its counterparties 0r posted cash collateral to its counterparties.

As of ~~March 31,~~June 30, 2021, 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 Swaps				Price Swaptions				Price Collars						Call Options Sold				Price Swaps				Price Swaptions				Price Collars						Call Options Sold
Period	Volume (Bbls/d)		Weighted Average Price ($/Bbl)		Volume (Bbls/d)		Weighted Average Price ($/Bbl)		Volume (Bbls/d)		Weighted Average Floor Price ($/Bbl)		Weighted Average Ceiling Price ($/Bbl)		Volume (Bbls/d)		Weighted Average Price ($/Bbl)		Volume (Bbls/d)		Weighted Average Price ($/Bbl)		Volume (Bbls/d)		Weighted Average Price ($/Bbl)		Volume (Bbls/d)		Weighted Average Floor Price ($/Bbl)		Weighted Average Ceiling Price ($/Bbl)		Volume (Bbls/d)		Weighted Average Price ($/Bbl)
Q2-Q4 2021		81,122	$	40.45		6,691	$	40.12		40,905	$	39.84	$	49.84		5,000	$	39.50
Q3-Q4 2021																				56,960	$	41.56		10,000	$	40.12		50,750	$	39.30	$	49.30		5,000	$	39.50
Q1-Q4 2022		25,619	$	43.82		10,323	$	46.46		15,733	$	44.92	$	54.92		—	$	—		25,619	$	43.82		10,323	$	46.46		20,233	$	46.41	$	56.41		—	$	—

As of ~~March 31,~~June 30, 2021, 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 and the end of month NYMEX index. The second table presents Devon’s natural gas derivatives that settle against the respective indices noted within the table.

	Price Swaps ⁽¹⁾				Price Swaptions ⁽²⁾				Price Collars ⁽²⁾						Call Options Sold ⁽²⁾				Price Swaps ⁽¹⁾				Price Swaptions ⁽²⁾				Price Collars ⁽²⁾						Call Options Sold ⁽²⁾
Period	Volume (MMBtu/d)		Weighted Average Price ($/MMBtu)		Volume (MMBtu/d)		Weighted Average Price ($/MMBtu)		Volume (MMBtu/d)		Weighted Average Floor Price ($/MMBtu)		Weighted Average Ceiling Price ($/MMBtu)		Volume (MMBtu/d)		Weighted Average Price ($/MMBtu)		Volume (MMBtu/d)		Weighted Average Price ($/MMBtu)		Volume (MMBtu/d)		Weighted Average Price ($/MMBtu)		Volume (MMBtu/d)		Weighted Average Floor Price ($/MMBtu)		Weighted Average Ceiling Price ($/MMBtu)		Volume (MMBtu/d)		Weighted Average Price ($/MMBtu)
Q2-Q4 2021		270,636	$	2.63		—	$	—		196,218	$	2.46	$	2.96		50,000	$	2.68
Q3-Q4 2021																				266,500	$	2.63		—	$	—		180,500	$	2.48	$	2.98		50,000	$	2.68
Q1-Q4 2022		3,452	$	2.85		100,000	$	2.70		69,110	$	2.54	$	3.04		—	$	—		3,452	$	2.85		100,000	$	2.70		113,110	$	2.57	$	3.07		—	$	—

	Natural Gas Basis Swaps						Natural Gas Basis Swaps
Period	Index	Volume (MMBtu/d)		Weighted Average Differential to Henry Hub ($/MMBtu)			Index	Volume (MMBtu/d)		Weighted Average Differential to Henry Hub ($/MMBtu)
Q2-Q4 2021	El Paso Natural Gas		35,000	$	(0.92	)
Q2-Q4 2021	WAHA		80,000	$	(0.65	)
Q3-Q4 2021							El Paso Natural Gas		35,000	$	(0.92	)
Q3-Q4 2021							WAHA		80,000	$	(0.65	)
Q1-Q4 2022	WAHA		70,000	$	(0.57	)	WAHA		70,000	$	(0.57	)
Q1-Q4 2023	WAHA		70,000	$	(0.51	)	WAHA		70,000	$	(0.51	)
Q1-Q4 2024	WAHA		40,000	$	(0.51	)	WAHA		40,000	$	(0.51	)

As of ~~March 31,~~June 30, 2021, Devon had the following open NGL derivative positions. Devon’s NGL positions settle against the average of the prompt month OPIS Mont Belvieu, Texas index.

The following table presents the derivative fair values by derivative financial instrument type followed by the corresponding individual consolidated balance sheets ~~caption.~~captions.

	March 31, 2021		December 31, 2020		June 30, 2021		December 31, 2020
Commodity derivative assets:
Other current assets	$	3	$	5	$	5	$	5
Other long-term assets		3		1		1		1
Total derivative assets	$	6	$	6	$	6	$	6
Commodity derivative liabilities:
Other current liabilities	$	667	$	143	$	968	$	143
Other long-term liabilities		122		5		157		5
Total derivative liabilities	$	789	$	148	$	1,125	$	148

The table below presents the share-based compensation expense included in Devon’s accompanying consolidated statements of comprehensive earnings. The vesting for certain share-based awards was accelerated in conjunction with the reduction of workforce described in Note 6 and is included in restructuring and transaction costs in the accompanying consolidated statements of comprehensive earnings.

	Three Months Ended March 31,				Six Months Ended June 30,
	2021		2020		2021		2020
G&A	$	20	$	20	$	40	$	39
Restructuring and transaction costs		21		—		21		—
Total	$	41	$	20	$	61	$	39

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

						Performance-Based					Performance												Performance-Based					Performance
	Restricted Stock Awards & Units					Restricted Stock Awards					Share Units							Restricted Stock Awards & Units					Restricted Stock Awards					Share Units
	Awards/Units			Weighted Average Grant-Date Fair Value		Awards			Weighted Average Grant-Date Fair Value		Units					Weighted Average Grant-Date Fair Value		Awards/Units			Weighted Average Grant-Date Fair Value		Awards			Weighted Average Grant-Date Fair Value		Units					Weighted Average Grant-Date Fair Value
	(Thousands, except fair value data)																	(Thousands, except fair value data)
Unvested at 12/31/20		5,316		$	25.82		44		$	44.70		1,994				$	31.89		5,316		$	25.82		44		$	44.70		1,994				$	31.89
Granted ⁽¹⁾		5,542		$	18.71		—		$	—		861				$	18.08		7,691		$	19.67		—		$	—		861				$	18.08
Vested		(4,329	)	$	22.63		(39	)	$	45.41		(754	)			$	37.40		(4,777	)	$	22.23		(44	)	$	44.70		(754	)			$	37.40
Forfeited		(20	)	$	24.79		—		$	—		(25	)			$	36.04		(69	)	$	23.45		—		$	—		(25	)			$	36.04
Unvested at 3/31/21		6,509		$	21.89		5		$	38.54		2,076		⁽²	⁾	$	24.12
Unvested at 6/30/21																			8,161		$	22.15		—		$	—		2,076		⁽²	⁾	$	24.12

The following table presents the assumptions related to the performance share units granted in 2021, as indicated in the previous summary table.

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,~~June 30, 2021.

			Performance-Based
	Restricted Stock		Restricted Stock		Performance		Restricted Stock		Performance
	Awards/Units		Awards		Share Units		Awards/Units		Share Units
Unrecognized compensation cost	$	88	$	—	$	21	$	111	$	18
Weighted average period for recognition (years)		2.2		0.2		2.3		2.6		2.1

The following table presents a summary of Devon’s asset impairments. Unproved impairments shown below are included in exploration expenses in the consolidated statements of comprehensive earnings.

	Three Months Ended March 31,				Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020		2021		2020
Proved oil and gas assets	$	—	$	2,664	$	—	$	—	$	—	$	2,664
Other assets		—		2		—		—		—		2
Total asset impairments	$	—	$	2,666	$	—	$	—	$	—	$	2,666

Unproved impairments	$	1	$	110	$	1	$	3	$	2	$	113

Due to the reduced demand from the COVID-19 pandemic causing an unprecedented downturn in the price of oil and reductions in near-term capital investment, Devon recognized approximately $2.7 billion of proved asset impairments during the first quarter of 2020. These impairments related to the Anadarko Basin and Rockies fields in which the cost basis included acquisitions completed in 2016 and 2015, respectively, when commodity prices were much higher. During the first quarter of 2020, Devon also recognized $2 million of product line fill impairments.

Due to the downturn in the commodity price environment and reduced near-term investment as discussed above, Devon also recognized $~~110~~113 million of unproved impairments during the first ~~three~~six months of 2020, primarily in the Rockies field.

	Three Months Ended March 31,				Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020		2021		2020
Restructuring	$	143	$	—	$	23	$	—	$	166	$	—
Transaction costs		46		—		—		—		46		—
Total	$	189	$	—	$	23	$	—	$	212	$	—

In conjunction with the Merger closing, Devon recognized ~~$143~~$166 million of restructuring expenses during the first ~~quarter~~six months of 2021 related to employee severance and termination benefits, settlements and curtailments from defined retirement benefits and contract terminations. Of these expenses, ~~$37~~$40 million and $21 million resulted from settlements and curtailments of defined retirement benefits and accelerated vesting of share-based grants, respectively, which are non-cash charges. Additionally, in conjunction with the Merger closing, Devon recognized $46 million of transaction costs primarily comprised of bank, legal and accounting fees.

	Other			Other						Other			Other
	Current			Long-term						Current			Long-term
	Liabilities			Liabilities			Total			Liabilities			Liabilities			Total
Balance as of December 31, 2020	$	35		$	137		$	172		$	35		$	137		$	172
Changes related to 2021 workforce reductions		61			—			61			51			—			51
Changes related to prior years' restructurings		(2	)		(7	)		(9	)		(3	)		(15	)		(18	)
Balance as of March 31, 2021	$	94		$	130		$	224
Balance as of June 30, 2021										$	83		$	122		$	205

Balance as of December 31, 2019	$	20		$	1		$	21		$	20		$	1		$	21
Changes related to prior years' restructurings		(9	)		—			(9	)		(13	)		—			(13	)
Balance as of March 31, 2020	$	11		$	1		$	12
Balance as of June 30, 2020										$	7		$	1		$	8

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

The deferred income tax benefit recognized in the first ~~quarter~~six months of 2021 primarily relates to the Merger. As shown in Note 2, Devon recognized $254 million of deferred tax liabilities to account for the Merger. The recognition of these deferred tax liabilities

caused a decrease to Devon’s net deferred tax assets and a corresponding decrease to the valuation allowance Devon has recognized on its U.S. Federal deferred tax assets.

As of ~~March 31,~~June 30, 2021, Devon ~~continues~~continued to maintain a valuation allowance against materially all U.S. deferred tax assets. Devon continues to assess its valuation allowance position every quarter. Absent any additional objective negative evidence, and with the addition of subjective evidence such as forecasted taxable income, Devon may adjust the valuation allowance on its deferred tax assets in future periods.

In the table above, the “other” effect is composed primarily of permanent differences related to costs incurred in connection with the Merger. Such items represent ~~$15~~$18 million of income tax expense in the first ~~quarter~~six months of 2021.

~~The Coronavirus Aid, Relief, and Economic Security Act (“CARES Act”) became law on March 27, 2020. The CARES Act allows~~In the fourth quarter of 2020, Devon recorded a deferred tax asset representing the deductible outside basis difference in its investment in a consolidated subsidiary. In the second quarter of 2021, Devon realized this deferred tax asset, increasing its U.S. federal net operating losses generated in taxable years beginning after December 31, 2017 and before January 1, 2021 to be carried back five years to offset taxable income and recoup previously paid taxes. As a result, Devon is carrying back net operating losses generated in 2020 and 2019 to 2015 and 2014, respectively. Because the U.S. Federal income tax rate was higher in the carryback periods, Devon recognized an income tax benefit in the first quarter of 2020.loss carryforwards by $1.8 billion.

The following table reconciles net earnings (loss) from continuing operations and weighted-average common shares outstanding used in the calculations of basic and diluted net earnings (loss) per share from continuing operations.

	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
	2021			2020			2021			2020			2021			2020
Net earnings (loss) from continuing operations:
Net earnings (loss) from continuing operations	$	213		$	(1,691	)	$	256		$	(679	)	$	469		$	(2,370	)
Attributable to participating securities		(2	)		(1	)		(3	)		—			(5	)		(1	)
Basic and diluted earnings (loss) from continuing operations	$	211		$	(1,692	)	$	253		$	(679	)	$	464		$	(2,371	)
Common shares:
Common shares outstanding - total		654			383			677			383			666			383
Attributable to participating securities		(5	)		(6	)		(6	)		(6	)		(6	)		(6	)
Common shares outstanding - basic		649			377			671			377			660			377
Dilutive effect of potential common shares issuable		2			—			2			—			2			—
Common shares outstanding - diluted		651			377			673			377			662			377
Net earnings (loss) per share from continuing operations:
Basic	$	0.33		$	(4.48	)	$	0.38		$	(1.80	)	$	0.70		$	(6.29	)
Diluted	$	0.32		$	(4.48	)	$	0.38		$	(1.80	)	$	0.70		$	(6.29	)
Antidilutive options		—			—

	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
	2021			2020			2021			2020			2021			2020
Pension and postretirement benefit plans:
Beginning accumulated pension and postretirement benefits	$	(127	)	$	(119	)	$	(104	)	$	(118	)	$	(127	)	$	(119	)
Recognition of net actuarial loss and prior service cost in earnings ⁽¹⁾		1			2			—			1			1			3
Settlement of pension benefits ⁽²⁾		15			—			3			—			18			—
Income tax expense		—			(1	)		—			—			—			(1	)
Other ⁽³⁾		7			—			—			—			7			—
Accumulated other comprehensive loss, net of tax	$	(104	)	$	(118	)	$	(101	)	$	(117	)	$	(101	)	$	(117	)

	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
	2021			2020			2021			2020			2021			2020
Changes in assets and liabilities, net:
Accounts receivable	$	(63	)	$	238		$	(100	)	$	80		$	(163	)	$	318
Income tax receivable		15			(113	)		121			1			136			(112	)
Other current assets		(25	)		(38	)		(33	)		30			(58	)		(8	)
Other long-term assets		(10	)		(24	)		(14	)		—			(24	)		(24	)
Accounts payable		71			42
Revenues and royalties payable		(55	)		(113	)
Accounts payable and revenues and royalties payable								72			(189	)		88			(260	)
Other current liabilities		(33	)		(81	)		52			(16	)		19			(97	)
Other long-term liabilities		(27	)		33			(81	)		(5	)		(108	)		28
Total	$	(127	)	$	(56	)	$	17		$	(99	)	$	(110	)	$	(155	)
Supplementary cash flow data - total operations:
Interest paid	$	114		$	64		$	105		$	66		$	219		$	130
Income taxes paid (refunded)	$	(6	)	$	151		$	(106	)	$	21		$	(112	)	$	172

As of ~~March 31,~~June 30, 2021, Devon had approximately ~~$230~~$200 million of accrued capital expenditures included in total property and equipment, net and accounts payable on the consolidated balance sheets. As of December 31, 2020 (pre-merger), Devon had approximately $100 million of accrued capital expenditures in total property and equipment, net and accounts payable on the consolidated balance sheets. As of January 7, 2021 (date of Merger closing), Devon assumed approximately $150 million of accrued capital expenditures included in accounts payable.

	March 31, 2021			December 31, 2020			June 30, 2021			December 31, 2020
Oil, gas and NGL sales	$	742		$	335		$	858		$	335
Joint interest billings		127			57			128			57
Marketing and midstream revenues		181			195			181			195
Other		54			25			30			25
Gross accounts receivable		1,104			612			1,197			612
Allowance for doubtful accounts		(15	)		(11	)		(12	)		(11	)
Net accounts receivable	$	1,089		$	601		$	1,185		$	601

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

	March 31, 2021			December 31, 2020			June 30, 2021			December 31, 2020
Property and equipment:
Proved	$	35,119		$	27,589		$	35,761		$	27,589
Unproved and properties under development		2,692			392			2,458			392
Total oil and gas		37,811			27,981			38,219			27,981
Less accumulated DD&A		(23,985	)		(23,545	)		(24,492	)		(23,545	)
Oil and gas property and equipment, net		13,826			4,436			13,727			4,436
Other property and equipment		2,060			1,737			2,095			1,737
Less accumulated DD&A		(612	)		(780	)		(633	)		(780	)
Other property and equipment, net ⁽¹⁾		1,448			957			1,462			957
Property and equipment, net	$	15,274		$	5,393		$	15,189		$	5,393

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

	March 31, 2021			December 31, 2020			June 30, 2021			December 31, 2020
8.25% due August 1, 2023 ⁽¹⁾	$	242		$	—
5.25% due September 15, 2024 ⁽¹⁾		472			—
8.25% due August 1, 2023 ⁽¹⁾							$	242		$	—
5.25% due September 15, 2024 ⁽¹⁾								472			—
5.85% due December 15, 2025		485			485			485			485
5.75% due June 1, 2026 ⁽¹⁾		500			—
7.50% due September 15, 2027		73			73			73			73
5.25% due October 15, 2027 ⁽¹⁾		600			—
5.875% due June 15, 2028 ⁽¹⁾		325			—
4.50% due January 15, 2030 ⁽¹⁾		585			—
5.25% due October 15, 2027 ⁽¹⁾								390			—
5.875% due June 15, 2028 ⁽¹⁾								325			—
4.50% due January 15, 2030 ⁽¹⁾								585			—
7.875% due September 30, 2031		675			675			675			675
7.95% due April 15, 2032		366			366			366			366
5.60% due July 15, 2041		1,250			1,250			1,250			1,250
4.75% due May 15, 2042		750			750			750			750
5.00% due June 15, 2045		750			750			750			750
Net premium (discount) on debentures and notes		226			(20	)		171			(20	)
Debt issuance costs		(31	)		(31	)		(32	)		(31	)
Total debt	$	7,268		$	4,298
Less amount classified as short-term debt		226			—
Total long-term debt	$	7,042		$	4,298		$	6,502		$	4,298

Debt maturities as of June 30, 2021, excluding debt issuance costs, premiums and discounts, are as follows:

The following schedule includes the summary of the WPX debt Devon assumed upon closing of the Merger on January 7, 2021.

Devon has a $3.0 billion Senior Credit Facility. As of ~~March 31,~~June 30, 2021, Devon had 0 outstanding borrowings under the Senior Credit Facility and had issued $2 million in outstanding letters of credit under this facility. The 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-~~non-cash financial write-downs such as impairments. As of June 30, 2021, Devon was in compliance with this covenant with a debt-to-capitalization ratio of 25.6%.

In the first six months of 2021, Devon redeemed $43 million of the 6.00% senior notes due 2022, $175 million of the 5.875% senior notes due 2028, $315 million of the 4.50% senior notes due 2030, $210 million of the 5.25% senior notes due 2027 and $500 of the 5.75% senior notes due 2026. In the first six months of 2021, Devon recognized $30 million of gains on early retirement of debt, consisting of $89 million of non-cash premium accelerations, partially offset by $59 million of cash retirement costs. The gain on early retirement is included in financing costs, net in the consolidated statements of comprehensive earnings.

~~cash financial write-downs such as impairments. As of March 31, 2021, Devon was in compliance with this covenant with a debt-to-capitalization ratio of 27.4%.~~

In first quarter of 2021, Devon redeemed $43 million of the 6.00% senior notes due 2022, $175 million of the 5.875% senior notes due 2028 and $315 million of the 4.50% senior notes due 2030. In the first quarter of 2021, Devon recognized a $20 million gain on early retirement of debt, consisting of $47 million of non-cash premium accelerations partially offset by $27 million of cash retirement costs. The gain on early retirement is included in net financing costs in the consolidated comprehensive statements of earnings. Devon also redeemed $210 million of the 5.25% senior notes due 2027 in April 2021. In May 2021, Devon gave notice to exercise its early redemption to fully retire the 5.75% senior notes due 2026 in June 2021.

The following table presents Devon’s right-of-use assets and lease liabilities as of ~~March 31,~~June 30, 2021 and December 31, 2020.

	March 31, 2021						December 31, 2020						June 30, 2021						December 31, 2020
	Finance		Operating		Total		Finance		Operating		Total		Finance		Operating		Total		Finance		Operating		Total
Right-of-use assets	$	217	$	38	$	255	$	220	$	3	$	223	$	216	$	36	$	252	$	220	$	3	$	223
Lease liabilities:
Current lease liabilities ⁽¹⁾	$	8	$	23	$	31	$	8	$	1	$	9	$	8	$	23	$	31	$	8	$	1	$	9
Long-term lease liabilities		244		16		260		244		2		246		245		13		258		244		2		246
Total lease liabilities	$	252	$	39	$	291	$	252	$	3	$	255	$	253	$	36	$	289	$	252	$	3	$	255

(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.

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

	Three Months Ended March 31,						Six Months Ended June 30,
	2021			2020			2021			2020
Asset retirement obligations as of beginning of period	$	369		$	398		$	369		$	398
Assumed WPX obligations		98			—			98			—
Liabilities incurred		9			6			20			11
Liabilities settled and divested		(17	)		(13	)		(47	)		(21	)
Revision of estimated obligation		11			4			11			4
Accretion expense on discounted obligation		7			5			14			10
Asset retirement obligations as of end of period		477			400			465			402
Less current portion		22			14			15			11
Asset retirement obligations, long-term	$	455		$	386		$	450		$	391

	March 31, 2021		December 31, 2020		June 30, 2021		December 31, 2020
Assumed gathering, processing and transportation contracts	$	482	$	—	$	474	$	—
Pension and post retirement benefit obligations		225		243
Pension and postretirement benefit obligations						227		243
Commodity derivatives						157		5
Restructuring and transaction costs		130		137		122		137
Estimated future obligation under a performance guarantee		128		—		95		—
Commodity derivatives		122		5
Other		182		166		173		166
Total other long-term liabilities	$	1,269	$	551	$	1,248	$	551

Devon assumed fixed gathering, processing and transportation contracts in the Merger and recognized a liability related to the difference in the contractual and market rates of these contracts as of the date of the Merger. The terms of the contracts extend through 2038 and all relate to the Delaware Basin. This difference will be recognized as a reduction to production expenses as the associated reserves are produced over the life of the respective contracts. InFor the ~~first quarter of~~six months ended June 30, 2021, Devon recognized $8$16 million of non-cash amortization of these liabilities as a reduction of production expenses in the consolidated ~~statement~~statements of comprehensive earnings.

Additionally, in the Merger, Devon assumed a future obligation under a performance guarantee related to gathering and processing commitments for assets WPX sold in 2018 in which the purchaser of those assets is now not expected to have the financial

ability to satisfy the obligations. As of ~~March 31,~~June 30, 2021, Devon ~~has~~ recorded a ~~$164~~$129 million liability for the estimated potential exposure based on probability-weighted cash flows for the remainder of the contract term of five years. Of the ~~$164~~$129 million, ~~$128~~$95 million is included in other long-term liabilities and ~~$36~~$34 million is included in other current liabilities on the consolidated balance sheets as of ~~March 31,~~June 30, 2021.

On January 7, 2021, Devon and WPX completed an all-stock merger of equals. On the closing date of the Merger, each share of WPX common stock was automatically converted into the right to receive 0.5165 of a share of Devon common stock. Consequently, Devon issued approximately 290 million shares of Devon common stock to holders of WPX common stock to effect the Merger on January 7, 2021.

The table below provides information regarding purchases of Devon’s common stock that were made in 2020 under a share repurchase program that expired at the end of 2020 (shares in thousands).

Upon completion of the Merger, Devon continued its commitment to pay a quarterly dividend at a fixed rate and instituted a variable quarterly dividend, which is dependent on quarterly cash flows, among other factors. The following table summarizes Devon’s fixed and variable dividends for the first ~~quarter~~six months of 2021 and 2020, respectively.

In ~~May~~August 2021, Devon announced a cash dividend in the amount of ~~$0.34~~$0.49 per share payable in the ~~second~~third quarter of 2021. The dividend consists of a fixed quarterly dividend in the amount of approximately $74 million (or $0.11 per share) and a variable quarterly dividend in the amount of approximately ~~$155~~$257 million (or ~~$0.23~~$0.38 per share).

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.

On October 1, 2020, Devon completed the sale of its Barnett Shale assets to BKV for proceeds, net of purchase price adjustments, of $490 million. Additionally, the agreement provides for contingent earnout payments to Devon of up to $260 million

based upon future commodity prices, 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. The valuation of the future contingent earnout payments included within other current assets in the March 31, 2021 balance sheet was $66 million. The value was derived utilizing a Monte Carlo valuation model and qualifies as a level 3 fair value measurement.

The following table presents the amounts reported in the consolidated statements of comprehensive earnings as discontinued operations.

	Three Months Ended March 31, 2020			Three Months Ended June 30, 2020			Six Months Ended June 30, 2020
Oil, gas and NGL sales	$	92		$	77		$	169
Total revenues		92			77			169
Production expenses		74			74			148
Asset impairments ⁽¹⁾		179			—			179
Asset dispositions					(2	)		(2	)
General and administrative expenses		1			—			1
Financing costs, net		(2	)		—			(2	)
Other, net		(3	)		(4	)		(7	)
Total expenses		249			68			317
Loss from discontinued operations before income taxes		(157	)
Earnings (loss) from discontinued operations before income taxes					9			(148	)
Income tax benefit		(32	)		—			(32	)
Net loss from discontinued operations, net of tax	$	(125	)
Net earnings (loss) from discontinued operations, net of tax				$	9		$	(116	)

Devon is party to various legal proceedings and other matters that may result in future payment obligations or other adverse consequences to its business. Matters that are probable of an unfavorable outcome to Devon and which any related potential payment obligation or other liability 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. While management does not believe any current matter is likely to involve future amounts that would be material to Devon’s financial position or results of operations after consideration of recorded accruals, the ultimate outcome of such matters and the amounts involved could differ materially from management’s estimates.

Numerous oil and natural gas producers and related parties, including Devon, have been named in various lawsuits alleging royalty underpayments. Devon is currently defending against a number of such lawsuits, either as a named defendant in the action or pursuant to indemnity obligations for the benefit of a third party. Plaintiffs in some of these lawsuits are seeking class certification. Among the allegations typically asserted in these suits are claims that Devon used below-market prices, made improper deductions, failed to “enhance” the value of gas through processing, used improper measurement techniques, entered into purchase and midstream arrangements with affiliates that resulted in underpayment of royalties or otherwise failed to prudently market oil, natural gas and NGLs produced and sold and pay royalties on the highest obtainable price. 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. Devon does not currently believe that it is subject to material exposure with respect to such royalty matters.

Devon’s business is subject to numerous federal, state, local and Native American tribal ~~and foreign~~ 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, the 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 believes these claims to be baseless and is vigorously defending 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 believes these claims to be baseless and intends to vigorously defend against the proceedings.

Direct and indirect purchasers of natural gas in various states filed individual and class action lawsuits against The Williams Companies, Inc. (“Williams”) and other parties alleging the manipulation of published gas price indices and seeking unspecified amounts of damages. WPX and certain of its subsidiaries, which were then affiliates of Williams, were also named as defendants in these actions. Such actions were transferred to the Nevada federal district court for consolidation of discovery and pre-trial issues. Although certain of the actions were subsequently settled or otherwise resolved, two putative class actions and an individual action remain unresolved.

The putative class actions have been remanded to their originally filed court, the Wisconsin federal district court, and class certification motions are pending. The individual action, Reorganized FLI Inc., has been remanded to its originally filed court, the

Kansas federal district court. The Tenth Circuit granted a petition to reconsider the denial of defendants’ motion for summary judgment, and the decision is pending after oral argument in January 2021.

~~Because of the uncertainty around pending unresolved issues, including an insufficient description of the purported classes and other related matters,~~ Devon cannot reasonably estimate a range of potential exposure at this time for these matters. In connection with its spin-off from Williams in 2011, WPX entered into a separation and distribution agreement with Williams, pursuant to which Williams agreed to indemnify and hold WPX and its subsidiaries harmless from any losses arising out of these 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. 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.

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,~~June 30, 2021 and December 31, 2020, as applicable. Therefore, such financial assets and liabilities are not presented in the following table. Additionally, information regarding the fair values of oil and gas assets is provided in Note 5.

							Fair Value Measurements Using:													Fair Value Measurements Using:
	Carrying			Total Fair			Level 1		Level 2			Level 3		Carrying			Total Fair			Level 1		Level 2			Level 3
	Amount			Value			Inputs		Inputs			Inputs		Amount			Value			Inputs		Inputs			Inputs
March 31, 2021 assets (liabilities):
June 30, 2021 assets (liabilities):
Cash equivalents	$	1,075		$	1,075		$	1,075	$	—		$	—	$	696		$	696		$	696	$	—		$	—
Commodity derivatives	$	6		$	6		$	—	$	6		$	—	$	6		$	6		$	—	$	6		$	—
Commodity derivatives	$	(789	)	$	(789	)	$	—	$	(789	)	$	—	$	(1,125	)	$	(1,125	)	$	—	$	(1,125	)	$	—
Debt	$	(7,268	)	$	(8,091	)	$	—	$	(8,091	)	$	—	$	(6,502	)	$	(7,630	)	$	—	$	(7,630	)	$	—
Contingent earnout payments	$	70		$	70		$	—	$	—		$	70	$	135		$	135		$	—	$	—		$	135
December 31, 2020 assets (liabilities):
Cash equivalents	$	1,436		$	1,436		$	1,436	$	—		$	—	$	1,436		$	1,436		$	1,436	$	—		$	—
Commodity derivatives	$	6		$	6		$	—	$	6		$	—	$	6		$	6		$	—	$	6		$	—
Commodity derivatives	$	(148	)	$	(148	)	$	—	$	(148	)	$	—	$	(148	)	$	(148	)	$	—	$	(148	)	$	—
Debt	$	(4,298	)	$	(5,365	)	$	—	$	(5,365	)	$	—	$	(4,298	)	$	(5,365	)	$	—	$	(5,365	)	$	—
Contingent earnout payments	$	66		$	66		$	—	$	—		$	66	$	66		$	66		$	—	$	—		$	66

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

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

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.

Contingent Earnout Payments – Devon has the right to receive contingent consideration related to the Barnett and non-core Rockies asset divestitures 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.

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~~and six-month periods ended ~~March 31,~~June 30, 2021 compared to previous periods and in our financial condition and liquidity since December 31, 2020. ~~For~~To help facilitate comparisons to the three-month period ended March 31, 2021, information regarding our first quarter 2021 financial results can be found in our First Quarter 2021 Quarterly Report on Form 10-Q . Additionally, for information regarding our critical accounting policies and estimates, see our 2020 Annual Report on Form 10-K under “Item 7. ~~Management’s Discussion and Analysis of Financial Condition and Results of Operations.”~~

A novel strain of coronavirus, SARS-CoV-2, causing a disease referred to as COVID-19, was reported to have surfaced in China in late 2019 and has subsequently spread to multiple countries worldwide, resulting in a global pandemic and health crisis. Devon began actively monitoring COVID-19 in January 2020 and formally established a COVID-19 cross-functional planning team at the beginning of March 2020. The COVID-19 team has remained focused on two key priorities: the health and safety of our employees and contractors and the uninterrupted operation of our business. For additional information regarding our actions in response to the COVID-19 pandemic, see our ~~2020 Annual Report on Form 10-K~~ ~~under “Item 2.~~ Management’s Discussion and Analysis of Financial Condition and Results of Operations.”

On September 26, 2020, we entered into the Merger Agreement, providing for an all-stock merger of equals with WPX which successfully closed on January 7, 2021. The Merger has created a leading unconventional oil producer in the U.S., with an asset base underpinned by premium acreage in the economic core of the Delaware Basin. This strategic combination accelerates our transition to a cash-return business model, including the implementation of a fixed plus variable dividend strategy. We remain focused on building economic value by executing on our strategic priorities of disciplined oil volume growth while capturing operational and corporate synergies, reducing 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:

We operate under a disciplined returns-driven strategy focused on delivering strong operational results, financial strength and value to our shareholders and continuing our commitment to environmental, social and governance excellence, which provides us with a strong foundation to grow returns, margin and profitability. We continue to execute on our strategy and navigate through ~~the challenged~~various economic ~~environment~~environments by protecting our financial strength, tailoring our capital investment to market conditions, improving our cash cost structure and preserving operational continuity.

After a significant downturn in economic activity in 2020 resulting from the unprecedented COVID-19 pandemic, economic activity has begun to recover, and commodity prices have continued to increase in 2021. However, we expect commodity prices to remain volatile with the emergence of COVID-19 variants and pending OPEC+ curtailment decisions. We will continue to evaluate the global impacts of COVID-19 as they evolve and will adapt accordingly as a company.

Trends of our quarterly earnings, operating cash flow, EBITDAX and capital expenditures are shown below. The quarterly earnings chart presents amounts pertaining to both Devon’s continuing and ~~discontinuing~~discontinued operations. The quarterly cash flow chart presents amounts pertaining to Devon’s continuing operations. Activity related to discontinued operations is only applicable for 2020 periods. “Core earnings” and “EBITDAX” are financial measures not prepared in accordance with GAAP. For a description of these measures, including reconciliations to the comparable GAAP measures, see “Non-GAAP Measures” in this Item 2.

Our net earnings in recent quarters have been significantly impacted by divestiture transactions, asset impairments and temporary, non-cash adjustments to the value of our commodity hedges. Net earnings in the second quarter of 2021, the first quarter of 2021, the fourth quarter of 2020 ~~the third quarter of 2020~~ and the ~~second~~third quarter of 2020 each included a hedge valuation loss, net of tax of $0.3 billion, $0.2 billion, $0.1 billion and $0.1 billion, ~~and $0.5 billion,~~ respectively. ~~Net earnings in the first quarter of 2020 included $2.3 billion of asset impairments on our proved and unproved properties and a $0.5 billion hedge valuation gain, both net of taxes.~~ Excluding these amounts, our core earnings have been more stable over recent quarters but continue to be heavily influenced by commodity prices.

Despite our portfolio enhancements, aggressive cost reductions and operational advancements, our financial results have been challenged by commodity prices and deterioration of the macro-economic environment resulting from the ~~unprecedented~~aforementioned COVID-19 ~~pandemic over the past year;~~pandemic; however, prices ~~began~~have begun to recover ~~in the second half of 2020~~ and ~~have~~increase significantly ~~increased~~ in ~~the first quarter of~~ 2021. Our earnings increased from the ~~fourth quarter of 2020 to the~~ first quarter of 2021 to the second quarter of 2021 primarily due to an increase in overall commodity prices as well as higher ~~volumes resulting from the Merger.~~sold volumes. Led by a ~~36%~~14% increase in WTI from the ~~fourth~~first quarter of ~~2020~~2021 to the ~~first~~second quarter of 2021, our unhedged combined realized price rose ~~55%~~7%. ~~These increases were partially offset by impacts related~~Volumes increased due to new well activity and restored production operations following winter storms in the ~~February 2021 winter storm which reduced~~ first ~~quarter volumes.~~quarter.

Like earnings, our operating cash flow is sensitive to volatile commodity prices. EBITDAX, which excludes financial amounts related to discontinued operations, and operating cash flows have been impacted by the COVID-19 pandemic and its impact on commodity prices. Our cash flow increased during the first ~~quarter~~and second quarters of 2021 primarily due to higher commodity prices and ~~the positive effects of the Merger.~~an increase in sold volumes.

We exited the ~~first~~second quarter of 2021 with ~~$4.9~~$4.5 billion of liquidity, comprised of ~~$1.9~~$1.5 billion of cash and $3.0 billion of available credit under our Senior Credit Facility. We currently have ~~$7.0~~$6.5 billion of debt outstanding with no maturities until ~~the latter half of~~

August 2023. We currently have approximately ~~50%~~45% and 60% of our remaining 2021 oil and gas production hedged, respectively, and 20% and 25% of our 2022 oil and gas production hedged, respectively. These contracts consist of collars and swaps based off the WTI oil

benchmark and the Henry Hub and NYMEX last day natural gas indices. Additionally, we have entered into regional basis swaps in an effort to protect price realizations across our portfolio.

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 earnings attributable to discontinued operations or noncontrolling interests.

Our ~~first~~second quarter 2021 net earnings were ~~$216~~$261 million, compared to a net ~~loss~~earnings of ~~$73~~$216 million for the ~~fourth~~first quarter of ~~2020.~~2021. The graph below shows the change in ~~the~~ net earnings ~~(loss)~~ from the ~~fourth~~first quarter of ~~2020~~2021 to the ~~first~~second quarter of 2021. The material changes are further discussed by category on the following pages.

Production Volumes

	Q1 2021		% of Total			Q4 2020		Change			Q2 2021		% of Total			Q1 2021		Change
Oil (MBbls/d)
Delaware Basin		172		64	%		99		+73	%		191		66	%		172		+11	%
Anadarko Basin		13		5	%		16		- 22	%		17		6	%		13		+29	%
Williston Basin		44		17	%		—	N/M				46		16	%		44		+3	%
Eagle Ford		16		6	%		18		- 10	%		18		6	%		16		+14	%
Powder River Basin		17		6	%		16		+6	%		16		5	%		17		- 4	%
Other		6		2	%		7		- 15	%		3		1	%		6		- 45	%
Total		268		100	%		156		+71	%		291		100	%		268		+9	%

	Q1 2021		% of Total			Q4 2020		Change			Q2 2021		% of Total			Q1 2021		Change
Gas (MMcf/d)
Delaware Basin		471		60	%		267		+77	%		513		58	%		471		+9	%
Anadarko Basin		200		25	%		233		- 14	%		225		26	%		200		+13	%
Williston Basin		49		6	%		—	N/M				61		7	%		49		+24	%
Eagle Ford		47		6	%		60		- 21	%		59		7	%		47		+25	%
Powder River Basin		21		3	%		22		- 4	%		21		2	%		21		+3	%
Other		3		0	%		2		+37	%		2		0	%		3		- 25	%
Total		791		100	%		584		+35	%		881		100	%		791		+11	%

	Q1 2021		% of Total			Q4 2020		Change			Q2 2021		% of Total			Q1 2021		Change
NGLs (MBbls/d)
Delaware Basin		60		61	%		43		+41	%		82		64	%		60		+36	%
Anadarko Basin		21		21	%		25		- 16	%		26		20	%		21		+21	%
Williston Basin		8		8	%		—	N/M				9		7	%		8		+21	%
Eagle Ford		6		6	%		9		- 31	%		9		7	%		6		+39	%
Powder River Basin		3		3	%		3		+6	%		3		2	%		3		- 4	%
Other		1		1	%		—	N/M				—		0	%		1		- 100	%
Total		99		100	%		80		+24	%		129		100	%		99		+30	%

	Q1 2021		% of Total			Q4 2020		Change			Q2 2021		% of Total			Q1 2021		Change
Combined (MBoe/d)
Delaware Basin		310		62	%		186		+67	%		358		63	%		310		+16	%
Anadarko Basin		68		14	%		81		- 16	%		80		14	%		68		+18	%
Williston Basin		61		12	%		—	N/M				66		12	%		61		+8	%
Eagle Ford		30		6	%		37		- 18	%		37		6	%		30		+21	%
Powder River Basin		23		5	%		22		+4	%		22		4	%		23		- 3	%
Other		7		1	%		7		-4	%		4		1	%		7		- 43	%
Total		499		100	%		333		+50	%		567		100	%		499		+14	%

From the ~~fourth~~first quarter of ~~2020~~2021 to the ~~first~~second quarter of 2021, the change in volumes contributed to a ~~$445~~$229 million increase in earnings. ~~Due~~The increase in volumes was primarily due to the Merger closing on January 7, 2021, volumes now include WPX legacy assets in the Delaware Basin in Texas and New Mexico and the Williston Basin in North Dakota. Volumes associated with these WPX legacy assets were approximately 200 MBoe/ddowntime in the first quarter ~~of 2021. The increase in volumes associated with the Merger were partially offset by impacts of~~related to the February ~~2021~~ winter ~~storm.~~storm and new well activity in the second quarter in the Delaware Basin. Volumes in the ~~second~~third quarter are expected to range from approximately ~~538~~566 to ~~561~~594 MBoe/d.

	Q1 2021			Realization	Q4 2020		Change			Q2 2021			Realization	Q1 2021			Change
Gas (per Mcf)
Henry Hub index	$	2.71			$	2.67		+1	%
NGLs (per Bbl)
WTI index										$	66.04			$	57.87			+14	%
Realized price, unhedged	$	2.91		107%	$	1.96		+48	%	$	23.89		36%	$	25.01			- 4	%
Cash settlements	$	(0.15	)		$	—				$	(0.25	)		$	(0.20	)
Realized price, with hedges	$	2.76		102%	$	1.96		+41	%	$	23.64		36%	$	24.81			- 5	%

	Q1 2021			Q4 2020			Change			Q2 2021			Q1 2021			Change
Combined (per Boe)
Realized price, unhedged	$	39.84		$	25.63			+55	%	$	41.75		$	39.14			+7	%
Cash settlements	$	(5.17	)	$	(0.86	)				$	(7.11	)	$	(5.17	)
Realized price, with hedges	$	34.67		$	24.77			+40	%	$	34.64		$	33.97			+2	%

From the ~~fourth~~first quarter of ~~2020~~2021 to the ~~first~~second quarter of 2021, field prices contributed to a ~~$557~~$168 million increase in earnings. Unhedged realized oil ~~gas and NGL~~ prices increased primarily due to higher WTI ~~Henry Hub and Mont Belvieu~~ index prices. ~~The increase in index prices~~This was partially offset by ~~a decrease~~lower unhedged realized gas and NGL prices which was primarily due to higher first quarter pricing contracts resulting from the winter storm and increased ethane rejection, respectively. The increase in WTI was also partially offset by an increase in hedge cash ~~settlements related to all products.~~settlement payments.

We currently have approximately ~~50%~~45% of our remaining 2021 oil production hedged with an average floor price of $40/Bbl and approximately 60% of our remaining 2021 gas production hedged with an average floor price of ~~$2.56/~~$2.57/Mcf. We ~~are continuing to build~~currently have approximately 20% of our ~~2021~~2022 oil production hedged with an average floor price of $45/Bbl and approximately 25% of our 2022 ~~hedge positions at market prices.~~gas production hedged with an average floor price of $2.64/Mcf.

	Q1 2021			Q4 2020			Change			Q2 2021			Q1 2021			Change
	Q									Q
Oil	$	(220	)	$	(27	)		- 715	%	$	(352	)	$	(220	)		- 60	%
Natural gas		(10	)		—		N/M				(12	)		(10	)		- 20	%
NGL		(2	)		—		N/M				(3	)		(2	)		- 50	%
Total cash settlements ⁽¹⁾	$	(232	)	$	(27	)		- 759	%	$	(367	)	$	(232	)		- 58	%

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 2021			Q4 2020			Change			Q2 2021			Q1 2021			Change
LOE	$	199		$	91			+119	%	$	210		$	199			+6	%
Gathering, processing & transportation		160			130			+23	%		147			129			+14	%
Production taxes		117			47			+149	%		143			117			+22	%
Property taxes		13			3			+333	%		13			13			+0	%
Total	$	489		$	271			+80	%	$	513		$	458			+12	%
Per Boe:
LOE	$	4.44		$	2.97			+49	%	$	4.06		$	4.44			- 9	%
Gathering, processing & transportation	$	3.57		$	4.23			- 16	%	$	2.85		$	2.87			- 1	%
Percent of oil, gas and NGL sales:
Production taxes		6.5	%		6.1	%		+8	%		6.7	%		6.6	%		+1	%

Production expenses increased from the ~~fourth~~first quarter of ~~2020~~2021 to the ~~first~~second quarter of 2021 primarily due to the Merger closing on January 7, 2021. Partially offsetting increases to gathering, processing and transportation costs were approximately $20 million of Anadarko volume commitments which expired at the end of 2020. LOE per Boe increased due to a different post-Merger asset mix as well asactivity impacts from the February 2021 winter ~~storm.~~storm and new well activity in the second quarter. Production taxes also increased due to the rise in commodity prices.

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 ~~prepared in accordance with~~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, ~~field~~realized prices and production expenses, shown above, had the following impact on our field-level cash margins by asset.

	Q1 2021		$ per BOE		Q4 2020		$ per BOE		Q2 2021		$ per BOE		Q1 2021		$ per BOE
Field-level cash margin (non-GAAP)
Field-level cash margin (Non-GAAP)
Delaware Basin	$	895	$	32.07	$	344	$	20.08	$	1,102	$	33.79	$	895	$	32.07
Anadarko Basin		85	$	14.01		61	$	8.28		145	$	19.86		85	$	14.01
Williston Basin		161	$	29.70		—	N/M			197	$	32.98		161	$	29.70
Eagle Ford		72	$	26.57		58	$	17.13		106	$	31.88		72	$	26.57
Powder River Basin		67	$	31.99		38	$	18.69		74	$	36.78		67	$	31.99
Other		19	$	28.21		13	$	18.35		17	$	42.85		19	$	28.21
Total	$	1,299	$	28.95	$	514	$	16.77	$	1,641	$	31.79	$	1,299	$	28.95

	Q1 2021		Q4 2020		Change			Q2 2021		Q1 2021		Change
Oil and gas per Boe	$	9.78	$	9.04		+8	%	$	9.88	$	9.78		+1	%

Oil and gas	$	439	$	278		+58	%	$	510	$	439		+16	%
Other property and equipment		28		23		+20	%	$	26		28		- 7	%
Total	$	467	$	301		+55	%	$	536	$	467		+15	%

Asset impairments	$	—	$	27	N/M

DD&A increased in the ~~first~~second quarter of 2021 primarily due to ~~the Merger closing on January 7, 2021. For additional information, see~~ ~~Note 2~~ ~~in “Part I. Financial Information – Item 1. Financial Statements” in this report.~~higher volumes.

~~Labor~~G&A decreased primarily as a result of lower employee costs and ~~benefits increased primarily due to the Merger closing on January 7, 2021. However, Devon’s G&A per Boe rate decreased nearly 10% due to synergies created by the Merger.~~benefits.

	Q1 2021			Q4 2020			Change in earnings			Q2 2021			Q1 2021			Change in earnings
Commodity hedge valuation changes ⁽¹⁾	$	(296	)	$	(90	)	$	(206	)	$	(336	)	$	(296	)	$	(40	)
Marketing and midstream operations		(21	)		(7	)		(14	)		1			(21	)		22
Exploration expenses		3			4			1			3			3			—
Asset dispositions		(32	)		(1	)		31			(87	)		(32	)		55
Net financing costs		77			70			(7	)		80			77			(3	)
Restructuring and transaction costs		189			17			(172	)		23			189			166
Other, net		(29	)		1			30			(14	)		(29	)		(15	)
							$	(337	)							$	185

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.

~~Net financing costs increased as a result of WPX debt assumed~~Asset dispositions in the ~~Merger, partially offset by a $20~~second quarter of 2021 includes $65 million ~~gain~~related to the re-valuation of contingent earnout payments associated with our ~~debt retirements in the first quarter of 2021.~~divested Barnett Shale assets. For additional information, see Note 132 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

Restructuring and transaction costs reflect workforce reductions in conjunction with the Merger, as well as various transaction costs related to the Merger. The majority of these costs were recorded in the first quarter of 2021. For additional information, see Note 6 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

Our ~~first quarter~~six months ended June 30, 2021 net earnings ~~was $216~~were $477 million, compared to a net loss of ~~$1.7~~$2.4 billion (excludes discontinued operations) for the ~~first quarter of~~six months ended June 30, 2020. The graph below shows the change in the net earnings (loss) from the ~~first quarter of~~six months ended June 30, 2020 to the ~~first quarter of~~six months ended June 30, 2021. The material changes are further discussed by category on the following pages.

Production Volumes

											Six Months Ended June 30,
	Q1 2021		% of Total			Q1 2020		Change			2021		% of Total			2020		Change
Oil (MBbls/d)
Delaware Basin		172		64	%		84		+105	%		181		65	%		81		+123	%
Anadarko Basin		13		5	%		24		- 45	%		15		5	%		22		- 34	%
Williston Basin		44		17	%		—	N/M				45		16	%		—	N/M
Eagle Ford		16		6	%		26		- 39	%		17		6	%		27		- 37	%
Powder River Basin		17		6	%		21		- 22	%		16		6	%		20		- 17	%
Other		6		2	%		8		- 27	%		5		2	%		8		- 40	%
Total		268		100	%		163		+64	%		279		100	%		158		+77	%

											Six Months Ended June 30,
	Q1 2021		% of Total			Q1 2020		Change			2021		% of Total			2020		Change
Gas (MMcf/d)
Delaware Basin		471		60	%		244		+93	%		492		59	%		242		+103	%
Anadarko Basin		200		25	%		272		- 26	%		213		25	%		267		- 20	%
Williston Basin		49		6	%		—	N/M				55		7	%		—	N/M
Eagle Ford		47		6	%		86		- 45	%		53		6	%		87		- 39	%
Powder River Basin		21		3	%		29		- 27	%		21		3	%		24		- 13	%
Other		3		0	%		3		- 26	%		2		0	%		4		- 39	%
Total		791		100	%		634		+25	%		836		100	%		624		+34	%

											Six Months Ended June 30,
	Q1 2021		% of Total			Q1 2020		Change			2021		% of Total			2020		Change
NGLs (MBbls/d)
Delaware Basin		60		61	%		37		+61	%		71		62	%		33		+114	%
Anadarko Basin		21		21	%		30		- 28	%		23		21	%		28		- 15	%
Williston Basin		8		8	%		—	N/M				9		8	%		—	N/M
Eagle Ford		6		6	%		9		- 30	%		8		7	%		10		- 26	%
Powder River Basin		3		3	%		3		+1	%		3		2	%		3		+7	%
Other		1		1	%		1		- 8	%		—		0	%		1		- 100	%
Total		99		100	%		80		+24	%		114		100	%		75		+53	%

											Six Months Ended June 30,
	Q1 2021		% of Total			Q1 2020		Change			2021		% of Total			2020		Change
Combined (MBoe/d)
Delaware Basin		310		62	%		162		+92	%		334		63	%		155		+116	%
Anadarko Basin		68		14	%		98		- 31	%		74		14	%		94		- 22	%
Williston Basin		61		12	%		—	N/M				63		12	%		—	N/M
Eagle Ford		30		6	%		50		- 39	%		33		6	%		52		- 35	%
Powder River Basin		23		5	%		29		- 20	%		23		4	%		27		- 14	%
Other		7		1	%		9		- 17	%		6		1	%		9		- 38	%
Total		499		100	%		348		+43	%		533		100	%		337		+58	%

From the ~~first quarter of~~six months ended 2020 to the ~~first quarter of~~six months ended 2021, the change in volumes contributed to ~~a $446~~an $841 million increase in earnings. Due to the Merger closing on January 7, 2021, volumes now include WPX legacy assets in the Delaware Basin in Texas and New Mexico and the Williston Basin in North Dakota. Volumes associated with these WPX legacy assets were approximately ~~200~~219 MBoe/d infor the ~~first quarter of~~six months ended 2021. Continued development of Devon legacy assets in the Delaware Basin also increased volumes. These increases were partially offset by impacts of the February 2021 winter storm and reduced activity across Devon’s remaining assets.

										Six Months Ended June 30,
	Q1 2021			Realization	Q1 2020		Change			2021			Realization	2020		Change
Gas (per Mcf)
Henry Hub index	$	2.71			$	1.95		+39	%	$	2.77			$	1.83		+51	%
Realized price, unhedged	$	2.91		107%	$	1.21		+141	%	$	2.58		93%	$	1.25		+106	%
Cash settlements	$	(0.15	)		$	0.36				$	(0.15	)		$	0.32
Realized price, with hedges	$	2.76		102%	$	1.57		+76	%	$	2.43		88%	$	1.57		+55	%

										Six Months Ended June 30,
	Q1 2021			Realization	Q1 2020		Change			2021			Realization	2020		Change
NGLs (per Bbl)
Mont Belvieu blended index ⁽¹⁾	$	25.81			$	14.39		+79	%
WTI index										$	61.95			$	37.43		+66	%
Realized price, unhedged	$	25.01		97%	$	10.40		+140	%	$	24.37		39%	$	9.70		+151	%
Cash settlements	$	(0.20	)		$	0.61				$	(0.23	)		$	0.56
Realized price, with hedges	$	24.81		96%	$	11.01		+125	%	$	24.14		39%	$	10.26		+135	%

									Six Months Ended June 30,
	Q1 2021			Q1 2020		Change			2021			2020		Change
Combined (per Boe)
Realized price, unhedged	$	39.84		$	25.43		+57	%	$	40.54		$	20.09		+102	%
Cash settlements	$	(5.17	)	$	3.20				$	(6.21	)	$	5.43
Realized price, with hedges	$	34.67		$	28.63		+21	%	$	34.33		$	25.52		+35	%

From the ~~first quarter of~~six months ended 2020 to the ~~first quarter of~~six months ended 2021, field prices contributed to a ~~$535 million~~$1.8 billion increase in earnings. Unhedged realized oil, gas and NGL prices increased primarily due to higher WTI, Henry Hub and Mont Belvieu index prices. The increase in index prices was partially offset by a decrease in hedge cash settlements related to all products.

	Q1 2021			Q1 2020		Change			Six Months Ended June 30,
	Q								2021			2020		Change
Oil	$	(220	)	$	76		- 389	%	$	(572	)	$	289		- 298	%
Natural gas		(10	)		21		- 148	%		(22	)		36		- 161	%
NGL		(2	)		4		- 150	%		(5	)		8		- 163	%
Total cash settlements ⁽¹⁾	$	(232	)	$	101		- 330	%	$	(599	)	$	333		- 280	%

Production Expenses

										Six Months Ended June 30,
	Q1 2021			Q1 2020			Change			2021			2020			Change
LOE	$	199		$	126			+58	%	$	409		$	234			+75	%
Gathering, processing & transportation		160			130			+23	%		276			253			+9	%
Production taxes		117			56			+109	%		260			81			+221	%
Property taxes		13			6			+117	%		26			13			+100	%
Total	$	489		$	318			+54	%	$	971		$	581			+67	%
Per Boe:
LOE	$	4.44		$	3.96			+12	%	$	4.24		$	3.83			+11	%
Gathering, processing & transportation	$	3.57		$	4.11			- 13	%	$	2.86		$	4.13			- 31	%
Percent of oil, gas and NGL sales:
Production taxes		6.5	%		6.9	%		- 5	%		6.7	%		6.6	%		+2	%

Production expenses increased ~~from the first quarter of 2020 to the first quarter of 2021~~ primarily due to the Merger closing on January 7, 2021. For additional information, see Note 2 in “Part I. Financial Information – Item 1. Financial Statements” in this report. Partially offsetting increases to gathering, processing and transportation costs were approximately ~~$10~~$23 million of Anadarko volume commitments which expired at the end of 2020. Production taxes also increased due to the rise in commodity prices.

Field-Level Cash Margin

	Q1 2021		$ per BOE		Q1 2020		$ per BOE		Six Months Ended June 30,
Field-level cash margin (non-GAAP)
									2021		$ per BOE		2020		$ per BOE
Field-level cash margin (Non-GAAP)
Delaware Basin	$	895	$	32.07	$	260	$	17.72	$	1,997	$	33.00	$	366	$	12.97
Anadarko Basin		85	$	14.01		74	$	8.22		230	$	17.20		87	$	5.09
Williston Basin		161	$	29.70		—	N/M			358	$	31.42		—	N/M
Eagle Ford		72	$	26.57		87	$	19.20		178	$	29.50		109	$	11.58
Powder River Basin		67	$	31.99		54	$	20.48		141	$	34.36		74	$	15.31
Other		19	$	28.21		14	$	15.55		36	$	33.43		14	$	8.16
Total	$	1,299	$	28.95	$	489	$	15.41	$	2,940	$	30.48	$	650	$	10.60

DD&A increased in ~~the first quarter of~~ 2021 primarily due to the Merger closing on January 7, 2021. For additional information, see Note 2 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

information, see Note 3 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

The following table presents the major changes in cash and cash equivalents for the three and six months ended ~~March 31,~~June 30, 2021 and 2020.

	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
	2021			2020			2021			2020			2021			2020
Operating cash flow from continuing operations	$	592		$	529		$	1,093		$	150		$	1,685		$	679
WPX acquired cash		344			—			—			—			344			—
Divestitures of property and equipment		15			25			49			3			64			28
Capital expenditures		(499	)		(425	)		(504	)		(307	)		(1,003	)		(732	)
Debt activity, net		(560	)		—			(742	)		—			(1,302	)		—
Repurchases of common stock		—			(38	)		—			—			—			(38	)
Common stock dividends		(203	)		(34	)		(229	)		(42	)		(432	)		(76	)
Noncontrolling interest activity, net		(28	)		2			(2	)		3			(30	)		5
Other		(20	)		(21	)		(4	)		(1	)		(24	)		(22	)
Net change in cash, cash equivalents and restricted cash from discontinued operations		—			(155	)		—			136			—			(19	)
Net change in cash, cash equivalents and restricted cash	$	(359	)	$	(117	)	$	(339	)	$	(58	)	$	(698	)	$	(175	)
Cash, cash equivalents and restricted cash at end of period	$	1,878		$	1,727		$	1,539		$	1,669		$	1,539		$	1,669

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 grew ~~12%~~approximately 150% during the ~~three~~six months ended ~~March 31,~~June 30, 2021 compared to the ~~three~~six months ended ~~March 31,~~June 30, 2020. The increase was due to the Merger and prices significantly increasing in the first ~~quarter~~half of 2021. Despite our portfolio enhancements, aggressive cost reductions and operational advancements, our 2020 financial results were challenged by commodity prices and deterioration of the macro-economic environment resulting from the unprecedented COVID-19 pandemic.

During the first ~~three~~six months of 2021, we sold non-core ~~U.S.~~ assets for approximately ~~$15~~$64 million, net of customary purchase price adjustments. For additional information, please see Note 2 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

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,				Three Months Ended June 30,				Six Months Ended June 30,
	2021		2020		2021		2020		2021		2020
Delaware Basin	$	397	$	221	$	378	$	192	$	775	$	413
Anadarko Basin		9		8		9		10		18		18
Williston Basin		28		—		18		—		46		—
Eagle Ford		14		94		29		42		43		136
Powder River Basin		33		85		7		46		40		131
Other		—		3		—		3		—		6
Total oil and gas		481		411		441		293		922		704
Midstream		5		8		43		11		48		19
Other		13		6		20		3		33		9
Total capital expenditures	$	499	$	425	$	504	$	307	$	1,003	$	732

Capital expenditures consist primarily of amounts related to our oil and gas exploration and development operations, midstream operations and other corporate activities. Capital expenditures increased in 2021 primarily due to the Merger closing on January 7, 2021 and results now ~~including~~include activity related to WPX legacy assets in the Delaware Basin in Texas and New Mexico and the Williston

~~Williston~~ Basin in North Dakota. Our capital program is designed to operate within or near operating cash flow. This is evidenced by our operating cash flow funding all of our capital expenditures for the ~~three~~six months ended ~~March 31,~~June 30, 2021. Our capital investment program is driven by a disciplined allocation process focused on returns. Our capital expenditures are expected to range between $1.7 billion to $2.0 billion for the full year 2021.

Subsequent to the Merger closing, we redeemed ~~$43 million~~$1.2 billion of ~~6.00% notes, $175 million of 5.875% notes and $315 million of 4.50%~~senior notes in the first ~~quarter~~half of 2021. We also paid ~~$27~~$59 million of cash retirement costs related to these redemptions.

~~As part of~~The following table summarizes our ~~fixed dividend program, we paid~~ common stock dividends ~~of $76 million ($0.11 per share) and $34 million ($0.09 per share)~~ during the second quarter and total for the first ~~three~~six months of 2021 and ~~2020, respectively.~~2020. We raised our quarterly dividend by 22% to $0.11 per share in the second quarter of 2020. In addition to the fixed quarterly dividend, we paid a ~~$127 million ($0.19 per share)~~ variable dividend in the first ~~quarter~~and second quarters of 2021.

We repurchased 2.2 million shares of common stock for $38 million in the first ~~three~~six months of 2020. For additional information, see Note 17 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

During the first ~~three~~six months of 2021, we ~~did not~~ ~~receive any~~received $3 million of contributions from our noncontrolling interests in CDM and distributed $4$9 million to our noncontrolling interests in CDM. In the first quarter of 2021, we paid $24 million to purchase the noncontrolling interest portion of a partnership that WPX had formed to acquire minerals in the Delaware Basin.

During the first six months of 2020, we received $11 million in contributions from our noncontrolling interests in CDM and distributed $6 million to our noncontrolling interests in CDM.

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 land owners to enhance our existing portfolio of assets.

On January 7, 2021, Devon and WPX completed an all-stock merger of equals. With the Merger, we are accelerating our transition to a cash-return business model, which moderates growth, emphasizes capital efficiencies and prioritizes cash returns to shareholders. These principles will position Devon to be a consistent builder of economic value through the cycle. The post-merger scalability is expected to enhance Devon’s free cash flow, credit profile and decrease the overall cost of capital.

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 post-merger capital requirements as discussed in this section as well as accelerate our cash-return business model.

Key inputs into determining our planned capital investment isare 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~~second quarter of 2021, we held approximately ~~$1.9~~$1.5 billion of cash, inclusive of ~~$195~~$191 million of cash restricted primarily for retained obligations related to divested assets. Our operating cash flow forecasts are sensitive to many variables and include a measure of uncertainty as these variables may differ from our expectations.

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. We hedge our production in a manner that systematically places hedges for several quarters in advance, allowing us to maintain a disciplined risk management program as it relates to commodity price volatility. We supplement the systematic hedging program with discretionary hedges that take advantage of favorable market conditions. The key terms to our oil, gas and NGL derivative financial instruments as of ~~March 31,~~June 30, 2021 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, as commodity prices ~~begin to recover from the COVID-19 pandemic,~~have increased, we remain committed to a maintenance capital program for the foreseeable future. We do not intend to add any growth projects until market fundamentals recover, excess inventory clears up and OPEC+ curtailed volumes are effectively absorbed by the world markets.

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.

Cost savings from synergies resulting from the Merger are expected to be attained through cost reductions and efficiencies related to our capital programs, G&A, financing costs and production expenses. We anticipate the planned $600 million reduction of annualized costs will occur by year-end 2021. Approximately 35% of the reduced costs are related to our capital programs and the remainder relate to our operating expenses, including G&A, interest expense and production expenses.

Restructuring and Transaction Related Costs – The majority of the Merger-related restructuring and transaction ~~costs~~cost cash outflows were paid in the first ~~quarter~~six months of 2021 and the remaining costs will be paid mostly over the remaining ~~nine~~six months of 2021. These payments relate to workforce reductions and the associated employee severance benefits, costs to modify or abandon vendor contracts and the acceleration of certain employee benefits triggered by the Merger.

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 partners 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 collateral postings.

In conjunction with the Merger closing on January 7, 2021, we assumed a principal value of $3.3 billion of WPX debt. Subsequent to the Merger closing, we have reduced our debt by approximately ~~$530 million~~$1.2 billion in the first ~~quarter~~half of ~~2021. Additionally, we redeemed $210 million of 5.25% notes in April 2021. In May 2021, we gave notice to exercise our early redemption to fully retire the 5.75% senior notes due 2026 in June~~ 2021. We expect these redemptions to lower our annual cash net financing costs by approximately $70 million.

As of ~~March 31,~~June 30, 2021, we had approximately $3.0 billion of available borrowing capacity under our Senior Credit Facility. This credit facility supports our $3.0 billion of short-term credit under our commercial paper program. At ~~March 31,~~June 30, 2021, there were no borrowings under our commercial paper program, and we were in compliance with the Senior Credit Facility’s financial covenant.

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 production growth opportunities. 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 positive outlook. Our credit rating from Moody’s Investor Service is Ba1 with a positive 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.

Following the closing of the Merger, ~~Devon~~we initiated a new “fixed plus variable” dividend strategy. The fixed dividend is currently paid quarterly at a rate of $0.11 per share, and ~~the~~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. In addition to the fixed quarterly dividend, ~~Devon~~we may pay a variable dividend up to 50 percent of ~~its~~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 ~~Devon’s~~our financial results, cash requirements, future prospects, COVID-19 impacts and other factors deemed relevant by the Board.

Our 2021 exploration and development budget for the remainder of 2021 is expected to range from approximately ~~$1.1 billion~~$700 million to ~~$1.3 billion.~~$900 million.

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. Due primarily to significant cumulative losses, we recorded a full valuation allowance against U.S. deferred tax assets in 2020 and remain in a full valuation allowance position at ~~March 31,~~June 30, 2021. However, absent any additional objective negative evidence, and with the addition of subjective evidence such as forecasted taxable income, we may adjust the valuation allowance in future periods.

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. No ownership change has occurred during 2021 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 three years.

Periodically we acquire assets and assume liabilities in transactions accounted for as business combinations, such as the Merger with WPX. In connection with the Merger, as the accounting acquirer, we allocated the $5.4 billion of purchase price consideration to the assets acquired and liabilities assumed based on estimated fair values as of the date of the Merger. The preliminary purchase price assessment remains an ongoing process and is subject to change for up to one year subsequent to the closing date of the Merger.

We made a number of assumptions in estimating the fair value of assets acquired and liabilities assumed in the Merger. The most significant assumptions relate to the estimated fair values of proved and unproved oil and gas properties. Since sufficient market data was not available regarding the fair values of proved and unproved oil and gas properties, we prepared estimates and engaged third party valuation experts. Significant judgments and assumptions are inherent in these estimates and include, among other things, estimates of reserve quantities, estimates of future commodity prices, drilling plans, expected development costs, lease operating costs, reserve risk adjustment factors and an estimate of an applicable market participant discount rate that reflects the risk of the underlying cash flow estimates.

Estimated fair values ascribed to assets acquired can have a significant impact on future results of operations presented in Devon’s financial statements. A higher fair value ascribed to a property results in higher DD&A expense, which results in lower net

earnings. Fair values are based on estimates of future commodity prices, reserve quantities, development costs and operating costs. In the event that future commodity prices or reserve quantities are lower than those used as inputs to determine estimates of acquisition date fair values, the likelihood increases that certain costs may be determined to not be recoverable.

In addition to the fair value of proved and unproved oil and gas properties, other significant fair value assessments for the assets acquired and liabilities assumed in the Merger relate to debt, the equity method investment in Catalyst ~~Midstream~~ and out-of-market contract assets and liabilities. The fair value of the assumed WPX publicly traded debt was based on available third party quoted prices. We prepared estimates and engaged third party valuation experts to assist in the valuation of the equity method investment in ~~Catalyst Midstream.~~Catalyst. Significant judgments and assumptions inherent in this estimate included projected Catalyst ~~Midstream~~ cash flows, comparable companies cash flow multiples and an estimate of an applicable market participant discount rate. The fair value of assumed out-of-market contract assets and liabilities associated with longer-term marketing, gathering, processing and transportation contracts included significant ~~judgements~~judgments and assumptions related to determining the market rates, estimates of future reserves and production associated with the respective contracts and applying an applicable market participant discount rate.

For additional information regarding our critical accounting policies and estimates, see our 2020 Annual Report on Form 10-K.

We make reference to “core earnings (loss) attributable to Devon” and “core earnings (loss) per share attributable to Devon” in “Overview of 2021 Results” in this Item 2 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 (loss) 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, non-cash asset impairments (including non-cash unproved asset impairments), deferred tax asset valuation allowance, changes in tax legislation, fair value changes in derivative financial instruments and foreign currency, costs associated with early retirement of debt, ~~fair value changes in derivative financial instruments, changes in tax legislation~~ and restructuring and transaction costs associated with the workforce reductions described further in Note 6.

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.

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

	Three Months Ended March 31,												Three Months Ended June 30,												Six Months Ended June 30,
	Before tax			After tax			After Noncontrolling Interests			Per Diluted Share			Before Tax			After Tax			After Noncontrolling Interests			Per Diluted Share			Before Tax			After Tax			After Noncontrolling Interests			Per Diluted Share
2021
Total
Earnings (loss) attributable to Devon (GAAP)	$	(32	)	$	216		$	213		$	0.32
Earnings attributable to Devon (GAAP)													$	304		$	261		$	256		$	0.38		$	272		$	477		$	469		$	0.70
Adjustments:
Asset dispositions		(32	)		(24	)		(24	)		(0.04	)		(87	)		(67	)		(67	)		(0.10	)		(119	)		(91	)		(91	)		(0.13	)
Asset and exploration impairments		1			—			—			0.00			1			1			1			0.00			2			1			1			0.00
Deferred tax asset valuation allowance		—			(263	)		(263	)		(0.40	)		—			(115	)		(115	)		(0.17	)		—			(378	)		(378	)		(0.57	)
Change in tax legislation														—			62			62			0.09			—			62			62			0.09
Fair value changes in financial instruments and foreign currency		294			225			225			0.34			334			258			258			0.38			628			483			483			0.72
Restructuring and transaction costs		189			162			162			0.25			23			21			21			0.03			212			183			183			0.28
Early retirement of debt		(20	)		(15	)		(15	)		(0.02	)		(10	)		(8	)		(8	)		(0.01	)		(30	)		(23	)		(23	)		(0.03	)
Core earnings attributable to Devon (Non-GAAP)	$	400		$	301		$	298		$	0.45		$	565		$	413		$	408		$	0.60		$	965		$	714		$	706		$	1.06
2020
Continuing Operations
Loss attributable to Devon (GAAP)	$	(2,107	)	$	(1,690	)	$	(1,691	)	$	(4.48	)	$	(680	)	$	(677	)	$	(679	)	$	(1.80	)	$	(2,787	)	$	(2,367	)	$	(2,370	)	$	(6.29	)
Adjustments:
Asset and exploration impairments		2,776			2,146			2,146			5.66			4			3			3			0.01			2,780			2,149			2,149			5.71
Deferred tax asset valuation allowance		—			108			108			0.28			—			149			149			0.39			—			257			257			0.67
Fair value changes in financial instruments		(619	)		(479	)		(479	)		(1.24	)		593			459			459			1.22			(26	)		(20	)		(20	)		(0.05	)
Change in tax legislation		—			(62	)		(62	)		(0.16	)		—			—			—			—			—			(62	)		(62	)		(0.16	)
Core earnings attributable to Devon (Non-GAAP)	$	50		$	23		$	22		$	0.06
Core loss attributable to Devon (Non-GAAP)													$	(83	)	$	(66	)	$	(68	)	$	(0.18	)	$	(33	)	$	(43	)	$	(46	)	$	(0.12	)
Discontinued Operations
Loss attributable to Devon (GAAP)	$	(157	)	$	(125	)	$	(125	)	$	(0.34	)
Earnings (loss) attributable to Devon (GAAP)													$	9		$	9		$	9		$	0.02		$	(148	)	$	(116	)	$	(116	)	$	(0.31	)
Adjustments:
Asset dispositions														(2	)		(1	)		(1	)		(0.00	)		(2	)		(1	)		(1	)		(0.00	)
Asset impairments		179			141			141			0.38			—			—			—			—			179			141			141			0.37
Fair value changes in foreign currency and other		10			10			10			0.03			(5	)		(6	)		(6	)		(0.02	)		5			4			4			0.01
Core earnings attributable to Devon (Non-GAAP)	$	32		$	26		$	26		$	0.07		$	2		$	2		$	2		$	0.00		$	34		$	28		$	28		$	0.07
Total
Loss attributable to Devon (GAAP)	$	(2,264	)	$	(1,815	)	$	(1,816	)	$	(4.82	)	$	(671	)	$	(668	)	$	(670	)	$	(1.78	)	$	(2,935	)	$	(2,483	)	$	(2,486	)	$	(6.60	)
Adjustments:
Continuing Operations		2,157			1,713			1,713			4.54			597			611			611			1.62			2,754			2,324			2,324			6.17
Discontinued Operations		189			151			151			0.41			(7	)		(7	)		(7	)		(0.02	)		182			144			144			0.38
Core earnings attributable to Devon (Non-GAAP)	$	82		$	49		$	48		$	0.13
Core earnings (loss) attributable to Devon (Non-GAAP)													$	(81	)	$	(64	)	$	(66	)	$	(0.18	)	$	1		$	(15	)	$	(18	)	$	(0.05	)

To assess the performance of our assets, we use EBITDAX and Field-Level Cash Margin. We compute EBITDAX as net earnings from continuing operations 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 continuing operations.

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

	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
	2021			2020			2021			2020			2021			2020
Net earnings (loss) (GAAP)	$	216		$	(1,815	)	$	261		$	(668	)	$	477		$	(2,483	)
Net loss from discontinued operations, net of tax		—			125
Net (earnings) loss from discontinued operations, net of tax								—			(9	)		—			116
Financing costs, net		77			65			80			69			157			134
Income tax benefit		(248	)		(417	)
Income tax expense (benefit)								43			(3	)		(205	)		(420	)
Exploration expenses		3			112			3			12			6			124
Depreciation, depletion and amortization		467			401			536			299			1,003			700
Asset impairments		—			2,666			—			—			—			2,666
Asset dispositions		(32	)		—			(87	)		—			(119	)		—
Share-based compensation		20			20			20			19			40			39
Derivative and financial instrument non-cash valuation changes		296			(619	)		336			593			632			(26	)
Restructuring and transaction costs		189			—			23			—			212			—
Accretion on discounted liabilities and other		(29	)		(48	)		(14	)		13			(43	)		(35	)
EBITDAX (non-GAAP)		959			490
EBITDAX (Non-GAAP)								1,201			325			2,160			815
Marketing and midstream revenues and expenses, net		21			18			(1	)		8			20			26
Commodity derivative cash settlements		232			(101	)		367			(232	)		599			(333	)
General and administrative expenses, cash-based		87			82			74			60			161			142
Field-level cash margin (non-GAAP)	$	1,299		$	489
Field-level cash margin (Non-GAAP)							$	1,641		$	161		$	2,940		$	650

As of ~~March 31,~~June 30, 2021, we have commodity derivatives that pertain to a portion of our estimated production for the last ~~nine~~six months of 2021, as well as for 2022, 2023 and 2024. 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,~~June 30, 2021, a 10% change in the forward curves associated with our commodity derivative instruments would have changed our net positions by approximately $335 million.

As of ~~March 31,~~June 30, 2021, we had total debt of ~~$7.3~~$6.5 billion. All of our debt is based on fixed interest rates averaging ~~5.6%~~5.7%.

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,~~June 30, 2021 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.

In conjunction with the Merger closing, we have integrated WPX’s operations into our overall system of internal controls over financial reporting and they are now included in our assessment of the effectiveness of our internal controls over financial reporting. For additional information regarding the Merger, see Note 2 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

There were no other 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.

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 ~~matter~~matters noted below, there were no material pending legal proceedings to which we are a party or to which any of our property is subject.

On April 7, 2020, WPX Energy, Inc., a wholly-owned subsidiary of the Company, received a notice of violation from the EPA relating to specific historical air emission events occurring on the Fort Berthold Indian Reservation in North Dakota. ~~We have since~~On June 4, 2021, we received ~~information~~a notice of violation from the EPA ~~that specifies~~relating to alleged air permit violations by WPX Energy Permian, LLC, a wholly-owned subsidiary of the ~~particular facilities to which the notice of violation applies. We have been~~Company, during 2020 in ~~the process of providing~~western Texas. The Company has engaged in ongoing communications with the EPA, ~~with additional~~including through the exchange of information, ~~regarding the specific events and responding~~ to ~~broader information requests from the EPA.~~resolve these matters. Although ~~this matter is~~these matters are ongoing and management cannot predict ~~its~~their ultimate outcome, the resolution of ~~this matter~~each of these matters may result in a fine or penalty in excess of $300,000.

There have been no material changes to the information included in Item 1A. “Risk Factors” in our 2020 Annual Report on Form 10-K.

The following table provides information regarding purchases of our common stock that were made by us during the ~~first~~second quarter of 2021 (shares in thousands).

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.

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)


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

Part I. Financial Information
Item 1.	Financial Statements	6
	Consolidated Statements of Comprehensive Earnings	6
	Consolidated Statements of Cash Flows	7
	Consolidated Balance Sheets	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	13
	Note 4 – Share-Based Compensation	15
	Note 5 – Asset Impairments	16
	Note 6 – Restructuring and Transaction Costs	17
	Note 7 – Income Taxes	1817
	Note 8 – Net Earnings (Loss) Per Share From Continuing Operations	1918
	Note 9 – Other Comprehensive Earnings (Loss)	1918
	Note 10 – Supplemental Information to Statements of Cash Flows	2019
	Note 11 – Accounts Receivable	2019
	Note 12 – Property, Plant and Equipment	20
	Note 13 – Debt and Related Expenses	2120
	Note 14 – Leases	22
	Note 15 – Asset Retirement Obligations	22
	Note 16 – Other Long-Term Liabilities	2322
	Note 17 – Stockholders’ Equity	23
	Note 18 – Discontinued Operations	2423
	Note 19 – Commitments and Contingencies	2524
	Note 20 – Fair Value Measurements	26
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	2827
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	4443
Item 4.	Controls and Procedures	4443

Part II. Other Information
Item 1.	Legal Proceedings	4544
Item 1A.	Risk Factors	4544
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	4544
Item 3.	Defaults Upon Senior Securities	4544
Item 4.	Mine Safety Disclosures	4544
Item 5.	Other Information	4544
Item 6.	Exhibits	4645

Signatures		4746

	Oil Basis Swaps
Period	Index	Volume (Bbls/d)		Weighted Average Differential to WTI ($/Bbl)
Q2-Q4 2021	Midland Sweet		22,669	$	0.84
Q2-Q4 2021	Guernsey Light Sweet		2,007	$	(1.48	)
Q2-Q4 2021	BRENT		1,000	$	(8.00	)
Q2-Q4 2021	NYMEX Roll		11,676	$	0.38
Q1-Q4 2022	BRENT		1,000	$	(7.75	)
Q1-Q4 2022	NYMEX Roll		16,000	$	0.37

	Oil Basis Swaps
Period	Index	Volume (Bbls/d)		Weighted Average Differential to WTI ($/Bbl)
Q3-Q4 2021	Midland Sweet		23,000	$	0.84
Q3-Q4 2021	Guernsey Light Sweet		4,000	$	(1.49	)
Q3-Q4 2021	BRENT		1,000	$	(8.00	)
Q3-Q4 2021	NYMEX Roll		13,000	$	0.39
Q1-Q4 2022	BRENT		1,000	$	(7.75	)
Q1-Q4 2022	NYMEX Roll		29,000	$	0.45


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

		Price Swaps
Period	Product	Volume (Bbls/d)		Weighted Average Price ($/Bbl)
Q2-Q4 2021	Natural Gasoline		1,000	$	47.57
Q2-Q4 2021	Normal Butane		1,000	$	31.40
Q2-Q4 2021	Propane		1,000	$	27.88

	2021
Grant-date fair value	$	18.08
Risk-free interest rate	0.18%
Volatility factor	67.8%
Contractual term (years)	2.89

	Total
2022	$	—
2023		242
2024		472
2025		485
2026		—
Thereafter		5,164
Total	$	6,363

	Face Value		Fair Value		Optional Redemption⁽¹⁾
6.00% due January 15, 2022	$	43	$	44
8.25% due August 1, 2023		242		281	June 1, 2023
5.25% due September 15, 2024		472		530	June 15, 2024
5.75% due June 1, 2026		500		529	June 1, 2021
5.25% due October 15, 2027		600		646	October 15, 2022
5.875% due June 15, 2028		500		554	June 15, 2023
4.50% due January 15, 2030		900		978	January 15, 2025
	$	3,257	$	3,562

	Total Number of Shares Purchased		Dollar Value of Shares Purchased		Average Price Paid per Share

First quarter 2020		2,243	$	38	$	16.85
Total		2,243	$	38	$	16.85

	Amounts		Rate Per Share
2021:
Fixed	$	76	$	0.11
Variable		127		0.19
Total	$	203	$	0.30
2020:
Fixed	$	34	$	0.09

	Q1 2021			Q4 2020
Current benefit	$	(5	)	$	(20	)
Deferred benefit		(243	)		(17	)
Total benefit	$	(248	)	$	(37	)
Effective income tax rate		763	%		33	%

	Q2 2021			Q1 2021
Current expense (benefit)	$	19		$	(5	)
Deferred expense (benefit)		24			(243	)
Total expense (benefit)	$	43		$	(248	)
Effective income tax rate		14	%		763	%

Period	Total Number of Shares Purchased ⁽¹⁾		Average Price Paid per Share
January 1 - January 31		15	$	18.29
February 1 - February 28		1,011	$	19.30
March 1 - March 31		798	$	22.92
Total		1,824	$	20.87

Exhibit Number		Description

4.1	~~Stockholders’ Agreement, by~~Supplemental Indenture No. 6, dated as of June 9, 2021, between the Company and ~~among Devon Energy Corporation, Felix Investment Holdings II, LLC, and EnCap Energy Capital Fund X, L.P., dated January 7, 2021~~UMB Bank, National Association, as trustee (incorporated by reference to Exhibit ~~10.1~~4.2 to ~~Registrant’s Current Report on~~the Company’s Form 8-K filed ~~January 7,~~June 9, 2021; File No. 001-32318).

4.2	~~Registration Rights Agreement, by~~Supplemental Indenture No. 7, dated as of June 9, 2021, between the Company and ~~between Devon Energy Corporation and Felix Investment Holdings II, LLC, dated January 7, 2021~~UMB Bank, National Association, as trustee (incorporated by reference to Exhibit ~~10.2~~4.3 to ~~Registrant’s~~the Company’s Form 8-K filed ~~January~~June 9, 2021; File No. 001-32318).

4.3	Supplemental Indenture No. 7, dated as of June 9, 2021, between WPX Energy, Inc. and The Bank of New York Mellon Trust Company, N.A., as trustee (incorporated by reference to Exhibit 4.5 to the Company’s Form 8-K filed June 9, 2021; File No. 001-32318).

4.4	Registration Rights Agreement, dated June 9, 2021, by and among the Company, BofA Securities, Inc., Citigroup Global Markets Inc. and Morgan Stanley & Co. LLC (incorporated by reference to Exhibit 10.1 to the Company’s Form 8-K filed June 9, 2021; File No. 001-32318).

10.1*	2021 Form of Notice of Grant of Restricted Stock Award and Award Agreement under the 2017 Long-Term Incentive Plan between ~~Devon Energy Corporation~~the Company and ~~certain officers~~all non-management directors for restricted stock ~~awarded.~~

10.2*	2021 Form of Notice of Grant of Performance Share Unit Award and Award Agreement under the 2017 Long-Term Incentive Plan between Devon Energy Corporation and certain officers for performance based restricted share units awarded.

10.3*	~~2021 Amendment (effective as of January 7, 2021) to the Devon Energy Corporation 2017 Long-Term Incentive Plan (incorporated by reference to Exhibit 10.7 to Registrant’s Form 10-K filed February 17, 2021; File No. 001-32318~~awarded).

10.4*	~~Employment Agreement, dated January 7, 2021, by and between Registrant and Richard E. Muncrief (incorporated by reference to Exhibit 10.3 to Registrant’s Form 8-K filed January 7, 2021; File No. 001-32318~~).

10.5*	~~Employment Agreement, dated January 7, 2021, by and between Registrant and Clay M. Gaspar (incorporated by reference to Exhibit 10.4 to Registrant’s Form 8-K filed January 7, 2021; File No. 001-32318~~).

10.6*	~~Employment Agreement, dated January 7, 2021, by and between Registrant and Dennis C. Cameron (incorporated by reference to Exhibit 10.5 to Registrant’s Form 8-K filed January 7, 2021; File No. 001-32318~~).

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).

				DEVON ENERGY CORPORATION

Date: ~~May 5,~~August 4, 2021				/s/ Jeremy D. Humphers
				Jeremy D. Humphers
				Senior Vice President and Chief Accounting Officer