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 22, 2020, ~~382.7~~382.8 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:

~~“ASR” means an accelerated share-repurchase transaction with a financial institution to repurchase Devon’s common stock.~~

“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.

“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 from our expectations due to a number of factors, including, but not limited to those, identified below.

The COVID-19 pandemic and its related repercussions have created significant volatility, uncertainty and turmoil in the global economy and our industry. This turmoil has included an unprecedented supply-and-demand imbalance for oil and other commodities, resulting in a swift and material decline in commodity prices in early 2020. Our future actual results could differ materially from the forward-looking statements in this report due to the COVID-19 pandemic and related impacts, including, among other things: contributing to a sustained or further deterioration in commodity prices; causing takeaway capacity constraints for production, resulting in production shut-ins and additional downward pressure on impacted regional pricing differentials; limiting our ability to access sources of capital due to disruptions in financial markets; increasing the risk of a downgrade from credit rating agencies; exacerbating counterparty credit risks and the risk of supply chain interruptions; and increasing the risk of operational disruptions due to social distancing measures and other changes to business practices.

In addition to the risks associated with the COVID-19 pandemic and its related impacts, our actual future results could differ materially from our expectations due to other factors, including, among other things:

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,
	2020			2019			2020			2019			2020			2019
	(Unaudited)						(Unaudited)
Upstream revenues	$	1,527		$	314
Oil, gas and NGL sales							$	424		$	936		$	1,231		$	1,855
Oil, gas and NGL derivatives								(361	)		140			359			(465	)
Marketing and midstream revenues		560			765			331			730			891			1,495
Total revenues		2,087			1,079			394			1,806			2,481			2,885
Production expenses		318			283			263			296			581			579
Exploration expenses		112			4			12			7			124			11
Marketing and midstream expenses		578			750			339			713			917			1,463
Depreciation, depletion and amortization		401			360			299			374			700			734
Asset impairments		2,666			—			—			—			2,666			—
Asset dispositions		—			(45	)		—			(2	)		—			(47	)
General and administrative expenses		102			135			79			114			181			249
Financing costs, net		65			60			69			66			134			126
Restructuring and transaction costs		—			51			—			12			—			63
Other expenses		(48	)		(22	)		13			7			(35	)		(15	)
Total expenses		4,194			1,576			1,074			1,587			5,268			3,163
Loss from continuing operations before income taxes		(2,107	)		(497	)
Income tax benefit		(417	)		(119	)
Net loss from continuing operations		(1,690	)		(378	)
Earnings (loss) from continuing operations before income taxes								(680	)		219			(2,787	)		(278	)
Income tax expense (benefit)								(3	)		68			(420	)		(51	)
Net earnings (loss) from continuing operations								(677	)		151			(2,367	)		(227	)
Net earnings (loss) from discontinued operations, net of income taxes		(125	)		61			9			344			(116	)		405
Net loss		(1,815	)		(317	)
Net earnings (loss)								(668	)		495			(2,483	)		178
Net earnings attributable to noncontrolling interests		1			—			2			—			3			—
Net loss attributable to Devon	$	(1,816	)	$	(317	)
Net earnings (loss) attributable to Devon							$	(670	)	$	495		$	(2,486	)	$	178
Basic net earnings (loss) per share:
Basic loss from continuing operations per share	$	(4.48	)	$	(0.89	)
Basic earnings (loss) from continuing operations per share							$	(1.80	)	$	0.37		$	(6.29	)	$	(0.54	)
Basic earnings (loss) from discontinued operations per share		(0.34	)		0.15			0.02			0.83			(0.31	)		0.96
Basic net loss per share	$	(4.82	)	$	(0.74	)
Basic net earnings (loss) per share							$	(1.78	)	$	1.20		$	(6.60	)	$	0.42
Diluted net earnings (loss) per share:
Diluted loss from continuing operations per share	$	(4.48	)	$	(0.89	)
Diluted earnings (loss) from continuing operations per share							$	(1.80	)	$	0.37		$	(6.29	)	$	(0.54	)
Diluted earnings (loss) from discontinued operations per share		(0.34	)		0.15			0.02			0.82			(0.31	)		0.96
Diluted net loss per share	$	(4.82	)	$	(0.74	)
Diluted net earnings (loss) per share							$	(1.78	)	$	1.19		$	(6.60	)	$	0.42
Comprehensive earnings (loss):
Net loss	$	(1,815	)	$	(317	)
Other comprehensive earnings, net of tax:
Net earnings (loss)							$	(668	)	$	495		$	(2,483	)	$	178
Other comprehensive earnings (loss), net of tax:
Foreign currency translation, discontinued operations		—			35			—			43			—			78
Release of Canadian cumulative translation adjustment, discontinued operations								—			(1,237	)		—			(1,237	)
Pension and postretirement plans		1			2			1			13			2			15
Other comprehensive earnings, net of tax		1			37
Comprehensive loss:		(1,814	)		(280	)
Other comprehensive earnings (loss), net of tax								1			(1,181	)		2			(1,144	)
Comprehensive loss							$	(667	)	$	(686	)	$	(2,481	)	$	(966	)
Comprehensive earnings attributable to noncontrolling interests		1			—			2			—			3			—
Comprehensive loss attributable to Devon	$	(1,815	)	$	(280	)	$	(669	)	$	(686	)	$	(2,484	)	$	(966	)

	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
	2020			2019			2020			2019			2020			2019
	(Unaudited)						(Unaudited)
Cash flows from operating activities:
Net loss	$	(1,815	)	$	(317	)
Adjustments to reconcile net loss to net cash from operating activities:
Net earnings (loss)							$	(668	)	$	495		$	(2,483	)	$	178
Adjustments to reconcile net earnings (loss) to net cash from operating activities:
Net (earnings) loss from discontinued operations, net of income taxes		125			(61	)		(9	)		(344	)		116			(405	)
Depreciation, depletion and amortization		401			360			299			374			700			734
Asset impairments		2,666			—			—			—			2,666			—
Leasehold impairments		110			1			3			1			113			2
Accretion on discounted liabilities		8			9			8			8			16			17
Total (gains) losses on commodity derivatives		(720	)		605			361			(140	)		(359	)		465
Cash settlements on commodity derivatives		101			31			232			23			333			54
Gains on asset dispositions		—			(45	)		—			(2	)		—			(47	)
Deferred income tax benefit		(311	)		(115	)
Deferred income tax expense (benefit)								—			65			(311	)		(50	)
Share-based compensation		20			44			19			25			39			69
Other		—			(14	)		4			2			4			(13	)
Changes in assets and liabilities, net		(56	)		(61	)		(99	)		(75	)		(155	)		(136	)
Net cash from operating activities - continuing operations		529			437			150			432			679			868
Cash flows from investing activities:
Capital expenditures		(425	)		(490	)		(307	)		(486	)		(732	)		(976	)
Acquisitions of property and equipment		(4	)		(10	)		(1	)		(13	)		(5	)		(23	)
Divestitures of property and equipment		25			310			3			28			28			338
Net cash from investing activities - continuing operations		(404	)		(190	)		(305	)		(471	)		(709	)		(661	)
Cash flows from financing activities:
Repayments of long-term debt		—			(162	)		—			—			—			(162	)
Repurchases of common stock		(38	)		(999	)		—			(187	)		(38	)		(1,185	)
Dividends paid on common stock		(34	)		(34	)		(42	)		(37	)		(76	)		(71	)
Contributions from noncontrolling interests		5			—			6			—			11			—
Distributions to noncontrolling interests		(3	)		—			(3	)		—			(6	)		—
Shares exchanged for tax withholdings		(17	)		(19	)
Shares exchanged for tax withholdings and other								—			(3	)		(17	)		(23	)
Net cash from financing activities - continuing operations		(87	)		(1,214	)		(39	)		(227	)		(126	)		(1,441	)
Net change in cash, cash equivalents and restricted cash of continuing operations		38			(967	)		(194	)		(266	)		(156	)		(1,234	)
Cash flows from discontinued operations:
Operating activities		(131	)		(59	)		(43	)		191			(174	)		131
Investing activities		(1	)		(59	)		171			2,536			170			2,478
Financing activities		—			(7	)		—			—			—			(7	)
Effect of exchange rate changes on cash		(23	)		1			8			37			(15	)		39
Net change in cash, cash equivalents and restricted cash of discontinued operations		(155	)		(124	)		136			2,764			(19	)		2,641
Net change in cash, cash equivalents and restricted cash		(117	)		(1,091	)		(58	)		2,498			(175	)		1,407
Cash, cash equivalents and restricted cash at beginning of period		1,844			2,446			1,727			1,355			1,844			2,446
Cash, cash equivalents and restricted cash at end of period	$	1,727		$	1,355		$	1,669		$	3,853		$	1,669		$	3,853

Reconciliation of cash, cash equivalents and restricted cash:
Cash and cash equivalents	$	1,527		$	1,327		$	1,474		$	3,470		$	1,474		$	3,470
Cash restricted for discontinued operations		200			—			195			370			195			370
Restricted cash included in other current assets		—			28			—			13			—			13
Total cash, cash equivalents and restricted cash	$	1,727		$	1,355		$	1,669		$	3,853		$	1,669		$	3,853

	March 31, 2020			December 31, 2019			June 30, 2020			December 31, 2019
	(Unaudited)						(Unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	1,527		$	1,464		$	1,474		$	1,464
Cash restricted for discontinued operations		200			380			195			380
Accounts receivable		594			832			515			832
Current assets associated with discontinued operations		736			896			748			896
Other current assets		998			279			446			279
Total current assets		4,055			3,851			3,378			3,851
Oil and gas property and equipment, based on successful efforts accounting, net		4,756			7,558			4,673			7,558
Other property and equipment, net ($89 and $80 million related to CDM in 2020 and 2019, respectively)		1,024			1,035
Other property and equipment, net ($96 million and $80 million related to CDM in 2020 and 2019, respectively)								1,013			1,035
Total property and equipment, net		5,780			8,593			5,686			8,593
Goodwill		753			753			753			753
Right-of-use assets		237			243			231			243
Other long-term assets		245			196			227			196
Long-term assets associated with discontinued operations		74			81			82			81
Total assets	$	11,144		$	13,717		$	10,357		$	13,717
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable	$	444		$	428		$	309		$	428
Revenues and royalties payable		617			730			473			730
Current liabilities associated with discontinued operations		294			459			441			459
Other current liabilities		199			310			229			310
Total current liabilities		1,554			1,927			1,452			1,927
Long-term debt		4,295			4,294			4,296			4,294
Lease liabilities		245			244			245			244
Asset retirement obligations		386			380			391			380
Other long-term liabilities		461			426			458			426
Long-term liabilities associated with discontinued operations		163			185			162			185
Deferred income taxes		—			341			—			341
Stockholders' equity:
Common stock, $0.10 par value. Authorized 1.0 billion shares; issued 383 million and 382 million shares in 2020 and 2019, respectively		38			38			38			38
Additional paid-in capital		2,701			2,735			2,720			2,735
Retained earnings		1,298			3,148			586			3,148
Accumulated other comprehensive loss		(118	)		(119	)		(117	)		(119	)
Total stockholders’ equity attributable to Devon		3,919			5,802			3,227			5,802
Noncontrolling interests		121			118			126			118
Total equity		4,040			5,920			3,353			5,920
Total liabilities and equity	$	11,144		$	13,717		$	10,357		$	13,717

										Retained			Other																					Retained			Other
							Additional			Earnings			Comprehensive																		Additional			Earnings			Comprehensive
	Common Stock						Paid-In			(Accumulated			Earnings			Treasury			Noncontrolling			Total			Common Stock						Paid-In			(Accumulated			Earnings			Treasury			Noncontrolling			Total
	Shares			Amount			Capital			Deficit)			(Loss)			Stock			Interests			Equity			Shares			Amount			Capital			Deficit)			(Loss)			Stock			Interests			Equity
	(Unaudited)																								(Unaudited)
Three Months Ended March 31, 2020
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
Three Months Ended June 30, 2019
Balance as of March 31, 2019																										417		$	42		$	3,518		$	3,280		$	1,064		$	(47	)	$	—		$	7,857
Net earnings																										—			—			—			495			—			—			—			495
Other comprehensive loss, net of tax																										—			—			—			—			(1,181	)		—			—			(1,181	)
Common stock repurchased																										—			—			—			—			—			(164	)		—			(164	)
Common stock retired																										(7	)		(1	)		(190	)		—			—			191			—			—
Common stock dividends																										—			—			—			(37	)		—			—			—			(37	)
Share-based compensation																										—			—			24			—			—			—			—			24
Balance as of June 30, 2019																										410		$	41		$	3,352		$	3,738		$	(117	)	$	(20	)	$	—		$	6,994
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
Three Months Ended March 31, 2019
Balance as of June 30, 2020																										383		$	38		$	2,720		$	586		$	(117	)	$	—		$	126		$	3,353
Six Months Ended June 30, 2019
Balance as of December 31, 2018		450		$	45		$	4,486		$	3,650		$	1,027		$	(22	)	$	—		$	9,186			450		$	45		$	4,486		$	3,650		$	1,027		$	(22	)	$	—		$	9,186
Effect of adoption of lease accounting		—			—			—			(19	)		—			—			—			(19	)		—			—			—			(19	)		—			—			—			(19	)
Net loss		—			—			—			(317	)		—			—			—			(317	)
Other comprehensive earnings, net of tax		—			—			—			—			37			—			—			37
Net earnings																										—			—			—			178			—			—			—			178
Other comprehensive loss, net of tax																										—			—			—			—			(1,144	)		—			—			(1,144	)
Restricted stock grants, net of cancellations		3			—			—			—			—			—			—			—			3			—			—			—			—			—			—			—
Common stock repurchased		—			—			—			—			—			(1,042	)		—			(1,042	)		—			—			—			—			—			(1,206	)		—			(1,206	)
Common stock retired		(36	)		(3	)		(1,014	)		—			—			1,017			—			—			(43	)		(4	)		(1,204	)		—			—			1,208			—			—
Common stock dividends		—			—			—			(34	)		—			—			—			(34	)		—			—			—			(71	)		—			—			—			(71	)
Share-based compensation		—			—			46			—			—			—			—			46			—			—			70			—			—			—			—			70
Balance as of March 31, 2019		417		$	42		$	3,518		$	3,280		$	1,064		$	(47	)	$	—		$	7,857
Balance as of June 30, 2019																										410		$	41		$	3,352		$	3,738		$	(117	)	$	(20	)	$	—		$	6,994

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 2019 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, 2020 and 2019 and Devon’s financial position as of ~~March 31,~~June 30, 2020. As further discussed in Note 17, Devon reached an agreement to sell its Barnett Shale assets in December 2019, which was amended in April 2020, and sold its Canadian operations ~~on June 27,~~in the second quarter of 2019. Activity relating to Devon’s Barnett Shale assets, inclusive of properties divested as partial sales of the Barnett Shale common operating field in previous reporting periods located primarily in Johnson and Wise counties, Texas, and its Canadian operations are classified as discontinued operations within Devon’s consolidated statements of comprehensive earnings and consolidated statements of cash flows. The associated assets and liabilities of Devon’s Barnett Shale assets and Canadian operations are presented as assets and liabilities associated with discontinued operations on the consolidated balance sheets.

During the fourth quarter of 2019, Devon entered into an agreement to form Cotton Draw Midstream, L.L.C. (“CDM”), a joint-venture entity in the Delaware Basin with an affiliate of QL Capital Partners, LP (“QLCP”). 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.

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,
	2020		2019			2020		2019		2020		2019
Oil	$	662	$	659		$	296	$	750	$	958	$	1,409
Gas		70		138			72		73		142		211
NGL		75		122			56		113		131		235
Oil, gas and NGL revenues from contracts with customers		807		919
Oil, gas and NGL derivatives		720		(605	)
Upstream revenues		1,527		314
Oil, gas and NGL sales							424		936		1,231		1,855

Oil		329		356			140		394		469		750
Gas		92		218			79		172		171		390
NGL		137		191			110		164		247		355
Total marketing revenues		558		765			329		730		887		1,495
Midstream revenues		2		—			2		—		4		—
Total marketing and midstream revenues from contracts with customers		560		765
Total revenues	$	2,087	$	1,079
Marketing and midstream revenues							331		730		891		1,495
Total revenues from contracts with customers						$	755	$	1,666	$	2,122	$	3,350

In 2016, the FASB issued ASU 2016-13, Financial Instruments-Credit Losses. This ASU changes the impairment model for trade receivables, held-to-maturity debt securities, net investments in leases, loans and other financial assets measured at amortized cost from the current “incurred loss” model to a new forward-looking “expected loss” model. Devon adopted this ASU in the first quarter of 2020 using the modified retrospective approach. Devon assesses credit risk by class of account type which includes cash equivalents and oil and gas, marketing and midstream, joint interest and other accounts receivable. These classes are then further evaluated using a probability weighted scenario assessment based on historical losses and a probability of future default. This evaluation is supported by an assessment of risk factors such as the age of receivable, current macro-economic conditions, credit rating of the counterparty and our historical loss rate. This adoption did not have a material impact on Devon’s consolidated financial statements.

In June 2019, Devon completed the sale of substantially all of its oil and gas assets and operations in Canada to Canadian Natural Resources Limited for proceeds, net of purchase price adjustments, of $2.6 billion ($3.4 billion Canadian dollars), and recognized a pre-tax gain of $223 million ($425 million, net of tax, primarily due to a significant deferred tax benefit). in 2019. Additional information can be found in Note 17.

Devon announced the sale of its Barnett Shale assets to BKV in December 2019 and subsequently amended the agreement in April 2020. Under the amended terms, Devon has agreed to sell its Barnett Shale assets for $570 million in cash, before purchase price adjustments, at closing, which ~~was extended to December 31,~~is scheduled for October 1, 2020. Under the terms of the agreement, Devon received deposit funds of $170 million in April 2020. Devon recognized a $748 million asset impairment related to these assets in the fourth quarter of 2019 and an incremental $179 million asset impairment during the first quarter of 2020. Additional information can be found in Note 17.

During the first quarter of 2020, Devon entered into a farmout agreement in which the ~~third-party~~third party to the agreement can participate in the development of certain Devon-owned non-operated interests in the Delaware Basin. Under the agreement, Devon will periodically transfer working interests to the third party, who will then fund its share of operating and development costs. Once certain investment hurdles are met, a portion of the working interest held by the third party will revert back to Devon. No material activity occurred during the first ~~quarter~~six months of 2020.

In the first quarter of 2019, Devon received proceeds of approximately $300 million and recognized a $45 million net gain on asset dispositions, primarily from sales of non-core assets in the Permian Basin. In aggregate, the total estimated proved reserves associated with these divested assets were approximately 25 MMBoe.

Devon enters into derivative financial instruments with respect to a portion of its oil, gas and NGL production to hedge future prices received. Additionally, Devon periodically enters into derivative financial instruments with respect to a portion of its oil, gas and NGL marketing activities. These commodity derivative financial instruments include financial price swaps, basis swaps and costless price collars. Devon periodically enters into interest rate swaps to manage its exposure to interest rate volatility. As of ~~March 31,~~June 30, 2020, 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, 2020, Devon ~~neither held~~did 0t hold any cash collateral of its ~~counterparties 0r posted collateral to its~~ counterparties.

As of ~~March 31,~~June 30, 2020, 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 Collars						Price Swaps				Price Collars
Period	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 Floor Price ($/Bbl)		Weighted Average Ceiling Price ($/Bbl)
Q2-Q4 2020		82,207	$	36.87		50,449	$	51.11	$	61.14
Q3-Q4 2020												87,750	$	36.65		43,500	$	50.96	$	60.96
Q1-Q4 2021		11,649	$	36.77		15,964	$	41.24	$	51.24		23,558	$	35.69		15,964	$	41.24	$	51.24

As of ~~March 31,~~June 30, 2020, Devon had the following open natural gas derivative positions. The first table presents Devon’s natural gas derivatives that settle against the Inside FERC first of the month Henry Hub index. The second table presents Devon’s natural gas derivatives that settle against the respective indices noted within the table.

	Price Swaps				Price Collars						Price Swaps				Price Collars
Period	Volume (MMBtu/d)		Weighted Average Price ($/MMBtu)		Volume (MMBtu/d)		Weighted Average Floor Price ($/MMBtu)		Weighted Average Ceiling Price ($/MMBtu)		Volume (MMBtu/d)		Weighted Average Price ($/MMBtu)		Volume (MMBtu/d)		Weighted Average Floor Price ($/MMBtu)		Weighted Average Ceiling Price ($/MMBtu)
Q2-Q4 2020		65,396	$	2.75		171,418	$	1.89	$	2.37
Q3-Q4 2020												59,150	$	2.69		180,000	$	1.96	$	2.45
Q1-Q4 2021		—	$	—		22,438	$	2.06	$	2.56		18,699	$	2.69		106,055	$	2.31	$	2.81

As of ~~March 31,~~June 30, 2020, 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 net gains and losses by derivative financial instrument type followed by the corresponding individual consolidated statements of comprehensive earnings caption.~~

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

	March 31, 2020		December 31, 2019		June 30, 2020		December 31, 2019
Commodity derivative assets:
Other current assets	$	616	$	49	$	95	$	49
Other long-term assets		27		1		6		1
Total derivative assets	$	643	$	50	$	101	$	50
Commodity derivative liabilities:
Other current liabilities	$	—	$	30	$	49	$	30
Other long-term liabilities		5		1		9		1
Total derivative liabilities	$	5	$	31	$	58	$	31

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 31st,				Six Months Ended June 30,
	2020		2019		2020		2019
G&A	$	20	$	23	$	39	$	44
Exploration expenses						—		1
Restructuring and transaction costs		—		22		—		24
Total	$	20	$	45	$	39	$	69
Related income tax benefit	$	—	$	9	$	—	$	10

Under its approved long-term incentive plan, Devon granted share-based awards to certain employees in the first ~~three~~six months of 2020. The following table presents a summary of Devon’s unvested restricted stock awards, performance-based restricted stock awards and performance share units granted under the plan.

						Performance-Based					Performance												Performance-Based					Performance
	Restricted Stock Awards					Restricted Stock Awards					Share Units							Restricted Stock Awards					Restricted Stock Awards					Share Units
	Awards			Weighted Average Grant-Date Fair Value		Awards			Weighted Average Grant-Date Fair Value		Units					Weighted Average Grant-Date Fair Value		Awards			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 12/31/19		4,984		$	29.65		153		$	33.88		2,155				$	40.35		4,984		$	29.65		153		$	33.88		2,155				$	40.35
Granted		2,865		$	22.54		—		$	—		688				$	27.89		3,051		$	21.93		—		$	—		688				$	27.89
Vested		(1,733	)	$	29.42		(105	)	$	29.12		(455	)			$	52.56		(1,847	)	$	29.26		(109	)	$	29.51		(455	)			$	52.56
Forfeited		(29	)	$	28.05		—		$	—		(304	)			$	52.56		(162	)	$	25.01		—		$	—		(364	)			$	48.66
Unvested at 3/31/20		6,087		$	26.37		48		$	44.12		2,084		⁽¹	⁾	$	31.79
Unvested at 6/30/20																			6,026		$	25.98		44		$	44.70		2,024		⁽¹	⁾	$	31.87

The following table presents the assumptions related to the performance share units granted in 2020, 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, 2020.

			Performance-Based						Performance-Based
	Restricted Stock		Restricted Stock		Performance		Restricted Stock		Restricted Stock		Performance
	Awards		Awards		Share Units		Awards		Awards		Share Units
Unrecognized compensation cost	$	120	$	—	$	25	$	107	$	—	$	19
Weighted average period for recognition (years)		2.9		1.2		1.8		2.7		0.9		1.8

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.

~~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~~.

Reduced demand from the COVID-19 pandemic caused an unprecedented downturn in the price of oil. As a result, Devon reduced planned 2020 capital investment by 45%. With materially lower commodity prices and reduced near-term investment, Devon assessed all of its oil and gas fields for impairment as of March 31, 2020. For impairment determinations, Devon historically utilized NYMEX forward strip prices for the first five years and applied internally generated price forecasts for subsequent years. In response to the COVID-19 pandemic, the NYMEX forward market became highly illiquid as evidenced by materially reduced trading volumes for periods beyond 2021. Therefore, Devon supplemented the NYMEX forward strip prices with price forecasts published by reputable investment banks and reservoir engineering firms to estimate future revenues as of March 31, 2020. To measure indicated impairments, Devon used a market-based weighted-average cost of capital to discount the future net cash flows. These inputs are categorized as level 3 in the fair value hierarchy.

Devon recognized approximately $2.7 billion of proved asset impairments during the first ~~three months~~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 than they are today. InDuring the first quarter of 2020, Devon recognized $2 million of product line fill impairments.

Due to the ~~recent~~ 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. ~~During the first three months of 2019, Devon allowed certain non-core acreage to expire without plans for development resulting in unproved impairments of $1 million.~~

During the first quarter of 2019, Devon announced workforce reductions and other initiatives designed to enhance its operational focus and cost structure in conjunction with the portfolio transformation ~~announcement further~~ discussed in Note 2. As a result, Devon recognized ~~$51~~$63 million of restructuring expenses during the first ~~three~~six months of 2019. Of these expenses, ~~$22~~$24 million resulted from accelerated vesting of share-based grants, which are noncash charges. Additionally, $5 million resulted from settlements of defined retirement benefits.

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

	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
	2020			2019			2020			2019			2020			2019
Loss from continuing operations before income taxes	$	(2,107	)	$	(497	)
Earnings (loss) from continuing operations before income taxes							$	(680	)	$	219		$	(2,787	)	$	(278	)

Current income tax benefit	$	(106	)	$	(4	)
Deferred income tax benefit		(311	)		(115	)
Total income tax benefit	$	(417	)	$	(119	)
Current income tax expense (benefit)							$	(3	)	$	3		$	(109	)	$	(1	)
Deferred income tax expense (benefit)								—			65			(311	)		(50	)
Total income tax expense (benefit)							$	(3	)	$	68		$	(420	)	$	(51	)

U.S. statutory income tax rate		21	%		21	%		21	%		21	%		21	%		21	%
State income taxes		1	%		6	%		0	%		9	%		1	%		3	%
Change in tax legislation		5	%		0	%		0	%		0	%		3	%		0	%
Other		(3	%)		(3	%)		(1	%)		1	%		(2	%)		(6	%)
Deferred tax asset valuation allowance		(4	%)		0	%		(20	%)		0	%		(8	%)		0	%
Effective income tax rate		20	%		24	%		0	%		31	%		15	%		18	%

Devon estimates its annual effective income tax rate to record its quarterly provision for income taxes in the various jurisdictions in which it operates. Statutory tax rate changes and other significant or unusual items are recognized as discrete items in the quarter in which they occur.

The Coronavirus Aid, Relief, and Economic Security Act (“CARES Act”) became law on March 27, 2020. The CARES Act allows 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 generate a refund. Devon intends to carry net operating losses generated in 2019 and 2020 back to 2014 and 2015, respectively. As a result, Devon recorded a $96 million income tax benefit ~~in Q1~~through the first six months of 2020, and expects to record an additional $9$2 million income tax benefit by the end of the year.

On July 28, 2020, the Department of Treasury issued final regulations regarding the provision of the Tax Cuts and Jobs Act that limits the deduction for business interest expense. Upon preliminary review of the regulations, there are provisions that may have a favorable impact to Devon. Upon completing a full review of the final regulations, Devon expects to record the effects of this tax legislation in the third quarter of 2020.

Throughout 2019, Devon maintained a valuation allowance against certain deferred tax assets, including certain tax credits and state net operating losses. Since then, reduced demand from the COVID-19 pandemic has caused an unprecedented downturn in the commodity price environment. As a result, Devon recorded significant impairments during the first quarter of 2020 and is now in a net deferred tax asset position. Devon reassessed its position and recorded a 100% valuation allowance against all net deferred tax assets as of March 31, 2020 ~~increasing its~~and remains in a full valuation allowance ~~by $108 million.~~position as of June 30, 2020.

Included in “other” in the table above is the impact of increasing Devon’s unrecognized tax benefits by approximately $34 million during the first quarter of 2020.

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,
	2020			2019			2020			2019			2020			2019
Net loss from continuing operations:
Net loss from continuing operations	$	(1,691	)	$	(378	)
Net earnings (loss) from continuing operations:
Net earnings (loss) from continuing operations							$	(679	)	$	151		$	(2,370	)	$	(227	)
Attributable to participating securities		(1	)		—			—			(2	)		(1	)		(1	)
Basic and diluted loss from continuing operations	$	(1,692	)	$	(378	)
Basic and diluted earnings (loss) from continuing operations							$	(679	)	$	149		$	(2,371	)	$	(228	)
Common shares:
Common shares outstanding - total		383			434			383			415			383			425
Attributable to participating securities		(6	)		(6	)		(6	)		(6	)		(6	)		(6	)
Common shares outstanding - basic and diluted		377			428
Net loss per share from continuing operations:
Common shares outstanding - basic								377			409			377			419
Dilutive effect of potential common shares issuable								—			2			—			—
Common shares outstanding - diluted								377			411			377			419
Net earnings (loss) per share from continuing operations:
Basic	$	(4.48	)	$	(0.89	)	$	(1.80	)	$	0.37		$	(6.29	)	$	(0.54	)
Diluted	$	(4.48	)	$	(0.89	)	$	(1.80	)	$	0.37		$	(6.29	)	$	(0.54	)
Antidilutive options ⁽¹⁾		—			1			—			1			—			1

	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
	2020			2019			2020			2019			2020			2019
Foreign currency translation:
Beginning accumulated foreign currency translation and other	$	—		$	1,159		$	—		$	1,194		$	—		$	1,159
Change in cumulative translation adjustment		—			35			—			43			—			78
Release of Canadian cumulative translation adjustment ⁽¹⁾								—			(1,237	)		—			(1,237	)
Ending accumulated foreign currency translation and other		—			1,194			—			—			—			—
Pension and postretirement benefit plans:
Beginning accumulated pension and postretirement benefits		(119	)		(132	)		(118	)		(130	)		(119	)		(132	)
Recognition of net actuarial loss and prior service cost in earnings ⁽¹⁾		2			3
Recognition of net actuarial loss and prior service cost in earnings ⁽²⁾								1			17			3			20
Income tax expense		(1	)		(1	)		—			(4	)		(1	)		(5	)
Ending accumulated pension and postretirement benefits		(118	)		(130	)		(117	)		(117	)		(117	)		(117	)
Accumulated other comprehensive earnings (loss), net of tax	$	(118	)	$	1,064
Accumulated other comprehensive loss, net of tax							$	(117	)	$	(117	)	$	(117	)	$	(117	)

	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
	2020			2019			2020			2019			2020			2019
Changes in assets and liabilities, net:
Accounts receivable	$	238		$	(29	)	$	80		$	39		$	318		$	10
Income tax receivable		(113	)		—			1			(1	)		(112	)		(1	)
Other current assets		(38	)		9			30			(6	)		(8	)		3
Other long-term assets		(24	)		(8	)		—			(7	)		(24	)		(15	)
Accounts payable		42			(51	)		(44	)		14			(2	)		(37	)
Revenues and royalties payable		(113	)		46			(145	)		(62	)		(258	)		(16	)
Other current liabilities		(81	)		(23	)		(16	)		(66	)		(97	)		(89	)
Other long-term liabilities		33			(5	)		(5	)		14			28			9
Total	$	(56	)	$	(61	)	$	(99	)	$	(75	)	$	(155	)	$	(136	)
Supplementary cash flow data - total operations:
Interest paid (net of capitalized interest)	$	64		$	53
Interest paid							$	66		$	108		$	130		$	161
Income taxes paid	$	151		$	6		$	21		$	10		$	172		$	16

As of June 30, 2020 and December 31, 2019, Devon had approximately $130 million and $250 million, respectively, of accrued capital expenditures included in “Total property and equipment, net” and “Accounts payable” on the consolidated balance sheets.

	March 31, 2020			December 31, 2019			June 30, 2020			December 31, 2019
Oil, gas and NGL sales	$	235		$	452		$	228		$	452
Joint interest billings		147			168			95			168
Marketing and midstream revenues		149			207			114			207
Other		74			13			88			13
Gross accounts receivable		605			840			525			840
Allowance for doubtful accounts		(11	)		(8	)		(10	)		(8	)
Net accounts receivable	$	594		$	832		$	515		$	832

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

	March 31, 2020			December 31, 2019			June 30, 2020			December 31, 2019
Property and equipment:
Proved	$	27,986		$	27,668		$	28,200		$	27,668
Unproved and properties under development		504			583			483			583
Total oil and gas		28,490			28,251			28,683			28,251
Less accumulated DD&A		(23,734	)		(20,693	)		(24,010	)		(20,693	)
Oil and gas property and equipment, net		4,756			7,558			4,673			7,558
Other property and equipment		1,732			1,725			1,735			1,725
Less accumulated DD&A		(708	)		(690	)		(722	)		(690	)
Other property and equipment, net ⁽¹⁾		1,024			1,035			1,013			1,035
Property and equipment, net	$	5,780		$	8,593		$	5,686		$	8,593

During the first ~~quarter~~six months of 2020, Devon recognized asset impairments of $2.7 billion primarily related to proved oil and gas assets and ~~$110~~$113 million of unproved impairments, which significantly reduced the carrying value of its property and equipment, net. See Note 5 for additional details.

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

	March 31, 2020			December 31, 2019
							June 30, 2020			December 31, 2019
5.85% due December 15, 2025	$	485		$	485		$	485		$	485
7.50% due September 15, 2027		73			73			73			73
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 discount on debentures and notes		(20	)		(20	)		(20	)		(20	)
Debt issuance costs		(34	)		(35	)		(33	)		(35	)
Total long-term debt	$	4,295		$	4,294		$	4,296		$	4,294

Devon has a $3.0 billion Senior Credit Facility. As of ~~March 31,~~June 30, 2020, 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 noncash financial write-downs such as impairments. As of ~~March 31,~~June 30, 2020, Devon was in compliance with this covenant with a debt-to-capitalization ratio of ~~18.8%~~19.3%.

In January 2019, Devon repaid the $162 million of 6.30% senior notes at maturity.

	Three Months Ended March 31,						Three Months Ended June 30,						Six Months Ended June 30,
	2020			2019			2020			2019			2020			2019
Interest based on debt outstanding	$	65		$	65		$	65		$	65		$	130		$	130
Interest income		(5	)		(11	)		(2	)		(7	)		(7	)		(18	)
Other		5			6			6			8			11			14
Total net financing costs	$	65		$	60		$	69		$	66		$	134		$	126

The following table presents Devon’s right-of-use assets and lease liabilities as of ~~March 31,~~June 30, 2020 and December 31, 2019.

	March 31, 2020						December 31, 2019						June 30, 2020						December 31, 2019
	Finance		Operating		Total		Finance		Operating		Total		Finance		Operating		Total		Finance		Operating		Total
Right-of-use assets	$	227	$	10	$	237	$	229	$	14	$	243	$	225	$	6	$	231	$	229	$	14	$	243
Lease liabilities:
Current lease liabilities ⁽¹⁾	$	7	$	7	$	14	$	7	$	10	$	17	$	7	$	4	$	11	$	7	$	10	$	17
Long-term lease liabilities		242		3		245		240		4		244		242		3		245		240		4		244
Total lease liabilities	$	249	$	10	$	259	$	247	$	14	$	261	$	249	$	7	$	256	$	247	$	14	$	261

(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,
	2020			2019			2020			2019
Asset retirement obligations as of beginning of period	$	398		$	484		$	398		$	484
Liabilities incurred		6			4			11			8
Liabilities settled and divested		(13	)		(33	)		(21	)		(39	)
Revision of estimated obligation		4			(62	)		4		��	(62	)
Accretion expense on discounted obligation		5			6			10			11
Asset retirement obligations as of end of period		400			399			402			402
Less current portion		14			15			11			15
Asset retirement obligations, long-term	$	386		$	384		$	391		$	387

During the first ~~three~~six months of 2019, Devon reduced its asset retirement obligations by $62 million, primarily due to changes in the future cost estimates and retirement dates for its oil and gas assets. Additionally, during the first ~~three~~six months of 2019, Devon reduced its asset retirement obligations by $29 million as a result of the non-core asset divestitures. For additional information, see Note 2.

In March 2018, Devon announced a $1.0 billion share repurchase program. In June 2018, Devon announced the expansion of this program to $4.0 billion. In February 2019, Devon announced a further expansion to $5.0 billion with a December 31, 2019 expiration date. In December 2019, Devon announced a new $1.0 billion share repurchase program with a December 31, 2020 expiration date. Under the new program, $800 million of the $1.0 billion authorization is conditioned upon the closing of the Barnett Shale divestiture for cash proceeds of at least $725 million. Due to the amended terms of the Barnett Shale divestiture with BKV, which reduced the closing payment to $570 million and extended the closing date to December 31, 2020, Devon does not anticipate being able to repurchase more than $200 million of the $1.0 billion authorization before the program expiration date. As the pricing and economic environment has changed due to the COVID-19 pandemic and demand challenges for commodities, Devon has temporarily suspended its share repurchase program to preserve liquidity.

The table below provides information regarding purchases of Devon’s common stock that were made under the respective share repurchase programs (shares in thousands).

Devon paid common stock dividends of $34 million ($0.09 per share) and $34 million ($0.08 per share) during the first three months of 2020 and 2019, respectively. In February 2020, Devon announced a 22% increase to its quarterly dividend, to $0.11 per

Devon raised its quarterly dividend by 22%, to $0.11 per share, beginning in the second quarter of 2020. In the second quarter of 2019, Devon ~~raised its~~increased the quarterly dividend rate from $0.08 to $0.09 per share.

On August 4, 2020, our Board of Directors approved a $0.26 per share (approximately $100 million total) special dividend to be payable as of October 1, 2020, to holders of record as of August 14, 2020.

In 2019, Devon announced that it had entered into an agreement to sell its Barnett Shale assets to BKV and subsequently amended the agreement in April 2020. Under the amended terms, Devon has agreed to sell its Barnett Shale assets for $570 million in cash, before purchase price adjustments, at closing, which ~~was extended to December 31,~~is scheduled for October 1, 2020. 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 commences on January 1, 2021 and has a term of four years. Under the terms of the agreement, Devon received ~~the~~ deposit funds of $170 million in April 2020. The deposit is being held by Devon pursuant to the terms of the sale agreement, which only requires Devon to return such funds to BKV in the event the transaction does not close as a result of Devon’s breach of its closing obligations. The deposit is classified as current liabilities associated with discontinued operations on Devon’s consolidated balance sheets.

In connection with the announced sale of its Barnett Shale assets, approximately $88 million of the U.S. reporting unit goodwill was allocated to the Barnett Shale assets. Additionally, Devon ceased depreciation for all property, plant and equipment classified as assets held for sale on the date the sales agreement was approved by the Board of Directors. Devon also recognized a $748 million asset impairment in the fourth quarter of 2019 related to these assets, primarily due to the difference between the net carrying value and the purchase price, net of estimated customary purchase price adjustments. During the first quarter of 2020, Devon adjusted the estimated impairment $179 million, primarily due to the amended agreement terms. The valuation of the future contingent earnout payments included in the March 31, 2020 Barnett Shale impairment computation was $41 million. The value was derived utilizing a Monte Carlo valuation model and qualifies as a level 3 fair value measurement.

As of ~~March 31,~~June 30, 2020, Devon has restricted approximately ~~$25~~$20 million of cash to fund obligations in connection with the abandonment of certain gas processing contracts related to divestitures of other Barnett Shale assets that occurred in 2018 and is classified as cash restricted for discontinued operations on the ~~2018 divestitures.~~consolidated balance sheets. Cash payments for these charges total approximately $2 million per quarter.

~~On June 27,~~In the second quarter of 2019, Devon completed the sale of its Canadian business for $2.6 billion ($3.4 billion Canadian dollars), net of purchase price adjustments, and recognized a pre-tax gain of $223 million ($425 million net of tax, primarily due to a significant deferred tax benefit). in 2019. Current (cash) income ~~tax~~and withholding taxes associated with the ~~sale was~~ Canadian business were

approximately ~~$150~~$175 million and ~~was~~were paid in the first ~~quarter~~half of 2020. The disposition of substantially all of Devon’s Canadian oil and gas assets resulted in Devon releasing its historical cumulative foreign currency translation adjustment of $1.2 billion from accumulated other comprehensive earnings to be included within the gain computation. The historical cumulative foreign currency translation portion of the gain is not taxable.

During the third quarter of 2019, Devon utilized a portion of the sales proceeds to early retire its $500 million of the 4.00% senior notes due July 15, 2021 and $1.0 billion of the 3.25% senior notes due May 15, 2022. Devon recognized a charge on the early retirement of these notes consisting of $52 million in cash retirement costs and $6 million of noncash charges.

As of ~~March 31,~~June 30, 2020, Devon has restricted approximately $175 million of ~~the Canadian~~ cash ~~balance is restricted for funding other~~to fund obligations retained related to the Canadian business and is classified as cash restricted for discontinued operations on the consolidated balance sheets. The remaining obligations consist of a firm transportation agreement and office leases. Cash payments for these charges total approximately $6 million per quarter.

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

	Three Months Ended June 30,								Six Months Ended June 30,
	Barnett Shale		Canada			Total			Barnett Shale			Canada			Total
2020
Oil, gas and NGL sales	$	77	$	—		$	77		$	169		$	—		$	169
Total revenues		77		—			77			169			—			169
Production expenses		74		—			74			148			—			148
Asset impairments		—		—			—			179			—			179
Asset dispositions		—		(2	)		(2	)		—			(2	)		(2	)
General and administrative expenses		—		—			—			—			1			1
Financing costs, net		—		—			—			—			(2	)		(2	)
Other expenses		2		(6	)		(4	)		(11	)		4			(7	)
Total expenses		76		(8	)		68			316			1			317
Earnings (loss) from discontinued operations before income taxes		1		8			9			(147	)		(1	)		(148	)
Income tax benefit		—		—			—			(32	)		—			(32	)
Net earnings (loss) from discontinued operations, net of tax	$	1	$	8		$	9		$	(115	)	$	(1	)	$	(116	)
2019
Oil, gas and NGL sales	$	115	$	379		$	494		$	264		$	730		$	994
Oil, gas and NGL derivatives		—		9			9			—			(95	)		(95	)
Marketing and midstream revenues		—		12			12			—			38			38
Total revenues		115		400			515			264			673			937
Production expenses		76		153			229			157			294			451
Exploration expenses		—		4			4			—			13			13
Marketing and midstream expenses		—		9			9			—			18			18
Depreciation, depletion and amortization		20		49			69			40			128			168
Asset impairments		—		37			37			—			37			37
Asset dispositions		1		(189	)		(188	)		2			(189	)		(187	)
General and administrative expenses		—		13			13			—			31			31
Financing costs, net		—		13			13			—			26			26
Restructuring and transaction costs		—		236			236			—			239			239
Other expenses		—		31			31			6			3			9
Total expenses		97		356			453			205			600			805
Earnings from discontinued operations before income taxes		18		44			62			59			73			132
Income tax expense (benefit)		3		(285	)		(282	)		12			(285	)		(273	)
Net earnings from discontinued operations, net of tax	$	15	$	329		$	344		$	47		$	358		$	405

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

~~The following table presents the~~ carrying amounts of the assets and liabilities associated with discontinued operations on the consolidated balance sheets.

	As of March 31, 2020						As of December 31, 2019						As of June 30, 2020						As of December 31, 2019
	Barnett Shale		Canada		Total		Barnett Shale		Canada		Total		Barnett Shale		Canada		Total		Barnett Shale		Canada		Total
Cash restricted for discontinued operations	$	25	$	175	$	200	$	25	$	355	$	380	$	20	$	175	$	195	$	25	$	355	$	380

Accounts receivable	$	36	$	1	$	37	$	38	$	1	$	39	$	47	$	2	$	49	$	38	$	1	$	39
Other current assets		5		2		7		5		2		7		5		2		7		5		2		7
Oil and gas property and equipment, based on successful efforts accounting, net		593		—		593		751		—		751		593		—		593		751		—		751
Other property and equipment, net		11		—		11		11		—		11		11		—		11		11		—		11
Goodwill		88		—		88		88		—		88		88		—		88		88		—		88
Other long-term assets		—		74		74		—		81		81		—		82		82		—		81		81
Total assets associated with discontinued operations	$	733	$	77	$	810	$	893	$	84	$	977	$	744	$	86	$	830	$	893	$	84	$	977

Accounts payable	$	14	$	6	$	20	$	15	$	4	$	19	$	18	$	3	$	21	$	15	$	4	$	19
Revenues and royalties payable		36		3		39		44		3		47		33		3		36		44		3		47
Other current liabilities		21		73		94		19		233		252		188		53		241		19		233		252
Asset retirement obligations		141		—		141		141		—		141		143		—		143		141		—		141
Other long-term liabilities		15		148		163		16		169		185		15		147		162		16		169		185
Total liabilities associated with discontinued operations	$	227	$	230	$	457	$	235	$	409	$	644	$	397	$	206	$	603	$	235	$	409	$	644

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

Numerous oil and natural gas producers and related parties, including Devon, have been named in various lawsuits alleging royalty underpayments. Devon is currently named as a defendant in a number of such lawsuits, including some lawsuits in which the plaintiffs seek to certify classes of similarly situated plaintiffs. Among the allegations typically asserted in these suits are claims that Devon used below-market prices, made improper deductions, used improper measurement techniques and entered into gas purchase and processing arrangements with affiliates that resulted in underpayment of royalties in connection with oil, natural gas and NGLs produced and sold. Devon is also involved in governmental agency proceedings and royalty audits and is subject to related contracts and regulatory controls in the ordinary course of business, some that may lead to additional royalty claims. Devon does not currently believe that it is subject to material exposure with respect to such royalty matters.

Devon is subject to certain laws and regulations relating to environmental remediation activities associated with past operations, such as the Comprehensive Environmental Response, Compensation, and Liability Act and similar state statutes. In response to liabilities associated with these activities, loss accruals primarily consist of estimated uninsured remediation costs. Devon’s monetary exposure for environmental matters is not expected to be material.

Beginning in 2013, various parishes in Louisiana filed suit against more than 100 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 is vigorously defending against these claims.

Various municipalities and other governmental and private parties in California have filed legal proceedings against certain 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 ~~injunctions against the production of all fossil fuels.~~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.

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, cash restricted for discontinued operations, 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, 2020 and December 31, 2019, 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			Carrying			Total Fair			Level 1		Level 2
	Amount			Value			Inputs		Inputs			Amount			Value			Inputs		Inputs
March 31, 2020 assets (liabilities):
June 30, 2020 assets (liabilities):
Cash equivalents	$	890		$	890		$	890	$	—		$	831		$	831		$	831	$	—
Commodity derivatives	$	643		$	643		$	—	$	643		$	101		$	101		$	—	$	101
Commodity derivatives	$	(5	)	$	(5	)	$	—	$	(5	)	$	(58	)	$	(58	)	$	—	$	(58	)
Debt	$	(4,295	)	$	(3,118	)	$	—	$	(3,118	)	$	(4,296	)	$	(4,382	)	$	—	$	(4,382	)
December 31, 2019 assets (liabilities):
Cash equivalents	$	702		$	702		$	702	$	—		$	702		$	702		$	702	$	—
Commodity derivatives	$	50		$	50		$	—	$	50		$	50		$	50		$	—	$	50
Commodity derivatives	$	(31	)	$	(31	)	$	—	$	(31	)	$	(31	)	$	(31	)	$	—	$	(31	)
Debt	$	(4,294	)	$	(5,376	)	$	—	$	(5,376	)	$	(4,294	)	$	(5,376	)	$	—	$	(5,376	)

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 ~~trade~~ in an established market. The fair values of its debt are estimated based on rates available for debt with similar terms and ~~maturity.~~maturity when active trading is not available.

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, 2020 compared to previous periods and in our financial condition and liquidity since December 31, 2019. For information regarding our critical accounting policies and estimates, see our 2019 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. The COVID-19 team is focused on two key priorities: the health and safety of our employees and contractors and the uninterrupted operation of our business.

This outbreak and the related responses of governmental authorities and others to limit the spread of the virus have significantly reduced global economic activity, resulting in an unprecedented decline in the demand for oil and other commodities. This supply-and-demand imbalance ~~has been~~was exacerbated by uncertainty regarding the future global supply of oil due to disputes between Russia and the members of OPEC ~~particularly Saudi Arabia,~~ in March 2020. These factors caused a swift and material deterioration in commodity prices in early 2020, with NYMEX WTI oil prices falling from a high of over $60/Bbl at the beginning of the year to below $20/Bbl in April 2020. ~~The current supply-and-demand imbalance has also imposed constraints on Devon’s and other operators’ ability~~By the end of the second quarter of 2020, NYMEX WTI oil prices recovered to ~~store and move production to downstream markets, which has resulted in the delay or curtailment of development activity, as well as the shutting-in of producing wells.~~approximately $40/Bbl.

~~In response to~~Despite the current ~~macro-economic environment,~~economic challenges, we ~~are protecting~~remain focused on building economic value by executing on our ~~financial strength~~strategic priorities of maximizing free cash flow, maintaining low leverage, delivering cash returns to our shareholders and ~~liquidity as evidenced by~~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 economic environment by protecting our financial strength, tailoring our capital investment to market conditions, improving our cash cost structure and preserving operational continuity.

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 operations. The quarterly cash flow chart presents amounts pertaining to Devon’s continuing operations. “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, noncash adjustments to the value of our commodity hedges. Net earnings in the second quarter of 2020 included a $0.5 billion hedge valuation loss, net of tax. 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. Net earnings in the fourth quarter of 2019 included $0.6 billion of asset impairments and a $0.1 billion hedge valuation loss, both net of taxes.Net earnings in the second quarter of 2019 included $0.3 billion for net after-tax gains and charges related to our Canadian disposition. ~~Net earnings in the first quarter of 2019 included a $0.5 billion after-tax hedge valuation loss.~~ 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 ~~continue to be~~were challenged by commodity prices and deterioration of the macro-economic environment resulting from the unprecedented COVID-19 pandemic. Our earnings declined from the ~~fourth~~first quarter of ~~2019~~2020 to the ~~first~~second quarter of 2020 due to a decrease in overall commodity prices. Led by a ~~19%~~39% decrease in ~~the~~ WTI from the ~~fourth~~first quarter of ~~2019~~2020 to the ~~first~~second quarter of 2020, our unhedged combined realized price dropped ~~23%~~44%. ~~Despite these~~In response to this commodity price ~~drops,~~environment, we were able to ~~maintain~~reduce our production ~~volumes while simultaneously reducing production~~and general and administrative costs 4%19% compared to ~~2019.~~the first quarter of 2020.

Like earnings, our operating cash flow is sensitive to volatile commodity prices. EBITDAX, which excludes financial amounts related to discontinued operations, ~~has been more stable over~~and operating cash flows were significantly lower during the ~~past five quarters as our production growth~~second quarter of 2020 resulting from impacts of the COVID-19 pandemic and ~~cost reductions~~

~~countered price~~ declines ~~experienced over the same time period. Regardless of cash flow fluctuations, we remain focused on managing our capital investment to generate free cash flow.~~in commodity prices. As operating cash flow has declined, we have ~~adjusted~~reduced our 2020 capital development plans ~~accordingly.~~approximately $800 million, or 45% compared to the original capital budget.

We exited the ~~first~~second quarter of 2020 with $4.7 billion of liquidity comprised of $1.7 billion of cash, inclusive of ~~$200~~$195 million of cash restricted for discontinued operations, and $3.0 billion of available credit under our Senior Credit Facility. We have $4.3 billion of debt outstanding with no maturities until the end of 2025. We currently have approximately ~~90%~~95% of our expected oil production and approximately 45% of our expected gas production protected with hedges for the remainder of 2020. These contracts consist of collars and swaps based off the WTI oil benchmark and the Henry Hub natural gas index. 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 noncontrolling interests. Analysis of the change in net earnings from continuing operations is shown below and analysis of the change in net earnings from discontinued operations is shown on page ~~33.~~36.

Our ~~first~~second quarter 2020 net loss from continuing operations was $677 million, compared to a net loss of $1.7 ~~billion.~~billion for the first quarter of 2020. The graph below shows the change in net ~~earnings (loss)~~loss from the ~~fourth~~first quarter of ~~2019~~2020 to the ~~first~~second quarter of 2020. The material changes are further discussed by category on the following pages. ~~To facilitate the review, these numbers are being presented before consideration of earnings attributable to noncontrolling interests.~~

~~Production Volumes~~

Q1 2020

% of Total

Q4 2019

Change

Oil (MBbls/d)

Delaware Basin

84

51
%

84

+0
%
Anadarko Basin

24

15
%

27

- 14
%
Powder River Basin

21

13
%

20

+7
%
Eagle Ford

26

16
%

23

+13
%
Other

8

5
%

9

- 6
%
Total

163

100
%

163

+0
%

Q1 2020

% of Total

Q4 2019

Change

Gas (MMcf/d)

Delaware Basin

244

38
%

234

+4
%
Anadarko Basin

272

43
%

295

- 8
%
Powder River Basin

29

4
%

28

+1
%
Eagle Ford

86

14
%

76

+12
%
Other

3

1
%

4

- 15
%
Total

634

100
%

637

- 1
%

Q1 2020

% of Total

Q4 2019

Change

NGLs (MBbls/d)

Delaware Basin

37

47
%

32

+18
%
Anadarko Basin

30

37
%

30

- 2
%
Powder River Basin

3

4
%

2

+13
%
Eagle Ford

9

11
%

9

+3
%
Other

1

1
%

1

- 17
%
Total

80

100
%

74

+8
%

Q1 2020

% of Total

Q4 2019

Change

Combined (MBoe/d)

Delaware Basin

162

47
%

154

+5
%
Anadarko Basin

98

28
%

107

- 8
%
Powder River Basin

29

8
%

27

+6
%
Eagle Ford

50

14
%

45

+11
%
Other

9

3
%

10

- 7
%
Total

348

100
%

343

+2
%

Production Volumes

	Q2 2020		% of Total			Q1 2020		Change
Oil (MBbls/d)
Delaware Basin		79		52	%		84		- 5	%
Powder River Basin		18		12	%		21		- 14	%
Eagle Ford		27		18	%		26		+4	%
Anadarko Basin		21		13	%		24		- 11	%
Other		8		5	%		8		- 6	%
Total		153		100	%		163		- 6	%

	Q2 2020		% of Total			Q1 2020		Change
Gas (MMcf/d)
Delaware Basin		241		39	%		244		- 1	%
Powder River Basin		20		3	%		29		- 29	%
Eagle Ford		87		14	%		86		+2	%
Anadarko Basin		262		43	%		272		- 4	%
Other		4		1	%		3		+13	%
Total		614		100	%		634		- 3	%

	Q2 2020		% of Total			Q1 2020		Change
NGLs (MBbls/d)
Delaware Basin		29		42	%		37		- 22	%
Powder River Basin		2		3	%		3		- 15	%
Eagle Ford		12		17	%		9		+27	%
Anadarko Basin		25		37	%		30		- 14	%
Other		1		1	%		1		- 37	%
Total		69		100	%		80		- 13	%

	Q2 2020		% of Total			Q1 2020		Change
Combined (MBoe/d)
Delaware Basin		149		46	%		162		- 8	%
Powder River Basin		24		7	%		29		- 17	%
Eagle Ford		53		16	%		50		+7	%
Anadarko Basin		90		28	%		98		- 8	%
Other		9		3	%		9		- 6	%
Total		325		100	%		348		- 7	%

~~Continued development~~

From the first quarter of 2020 to the second quarter of 2020, a decrease in volumes contributed to a $51 million decrease in earnings. Due to the ~~Delaware Basin~~challenged macro-economic environment, planned 2020 capital expenditures were reduced by 45% and ~~Powder River Basin drove production increases. Additionally, a well-control event curtailed production volumes in the Eagle Ford~~certain marginal wells were shut-in during the ~~fourth~~second quarter resulting in lower volumes. The majority of ~~2019. These were partially offset~~the shut-in production was restored by ~~lower activity in~~ the ~~Anadarko Basin.~~end of the second quarter.

In response to the challenged current macro-economic environment and the timing of completions, we ~~have reduced planned 2020 capital expenditures by 45% and shut in certain marginal wells. As a result, we anticipate total production~~expect volumes to ~~decrease in the second quarter of 2020 to a range of 302 to 328 MBoe/d and~~ continue to decrease for the second half of 2020. Volumes for the third quarter are expected to range from approximately 301 to 318 MBoe/d and improve in the fourth quarter due to timing of completions.

Field Prices

	Q1 2020		Realization		Q4 2019		Change			Q2 2020		Realization	Q1 2020		Change
Oil (per Bbl)
WTI index	$	46.44			$	57.02		- 19	%	$	28.42		$	46.44		- 39	%
Realized price, unhedged	$	44.59		96%	$	55.41		- 20	%	$	21.25	75%	$	44.59		- 52	%
Cash settlements	$	5.14			$	1.48				$	15.25		$	5.14
Realized price, with hedges	$	49.73		107%	$	56.89		- 13	%	$	36.50	128%	$	49.73		- 27	%

	Q1 2020		Realization		Q4 2019		Change			Q2 2020		Realization	Q1 2020		Change
Gas (per Mcf)
Henry Hub index	$	1.95			$	2.50		- 22	%	$	1.71		$	1.95		- 12	%
Realized price, unhedged	$	1.21		62%	$	1.70		- 29	%	$	1.29	76%	$	1.21		+7	%
Cash settlements	$	0.36			$	0.13				$	0.28		$	0.36
Realized price, with hedges	$	1.57		81%	$	1.83		- 14	%	$	1.57	92%	$	1.57		+0	%

	Q1 2020		Realization		Q4 2019		Change			Q2 2020		Realization	Q1 2020		Change
NGLs (per Bbl)
Mont Belvieu blended index ⁽¹⁾	$	14.39			$	18.69		- 23	%	$	12.57		$	14.39		- 13	%
Realized price, unhedged	$	10.40		72%	$	15.79		- 34	%	$	8.89	71%	$	10.40		- 15	%
Cash settlements	$	0.61			$	1.75				$	0.51		$	0.61
Realized price, with hedges	$	11.01		77%	$	17.54		- 37	%	$	9.40	75%	$	11.01		- 15	%

	Q1 2020		Q4 2019		Change			Q2 2020		Q1 2020		Change
Combined (per Boe)
Realized price, unhedged	$	25.43	$	32.82		- 23	%	$	14.37	$	25.43		- 44	%
Cash settlements	$	3.20	$	1.32				$	7.83	$	3.20
Realized price, with hedges	$	28.63	$	34.14		- 16	%	$	22.20	$	28.63		- 22	%

From the ~~fourth~~first quarter of ~~2019~~2020 to the ~~first~~second quarter of 2020, field prices contributed to a ~~$227~~$332 million decrease in earnings. Unhedged realized oil ~~gas~~ and NGL prices decreased primarily due to lower WTI ~~Henry Hub~~ and Mont Belvieu index prices. These decreases were partially offset by favorable hedge cash settlements across each of our products.

As prices ~~further~~ deteriorated towards the end of the first quarter from the COVID-19 pandemic, we added additional oil and gas hedges for the ~~remaining quarters~~remainder of 2020 and the year 2021. We currently have approximately ~~90%~~95% of our remaining 2020 oil production hedged with an average floor price of ~~$42/~~$41/Bbl and approximately 45% of our remaining 2020 gas production hedged with an average floor price of ~~$2.15/~~$2.20/Mcf. Additionally, we ~~are currently building~~continue to build our 2021 hedge positions at market prices.

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 2020			Q4 2019			Change			Q2 2020			Q1 2020			Change
LOE	$	126		$	120			+5	%	$	108		$	126			- 14	%
Gathering, processing & transportation		130			131			- 1	%		123			130			- 5	%
Production taxes		56			69			- 19	%		25			56			- 55	%
Property taxes		6			4			+50	%		7			6			+2	%
Total	$	318		$	324			- 2	%	$	263		$	318			- 17	%
Per Boe:
LOE	$	3.96		$	3.79			+5	%	$	3.69		$	3.96			- 7	%
Gathering, processing & transportation	$	4.11		$	4.16			- 1	%	$	4.16		$	4.11			+1	%
Percent of oil, gas and NGL sales:
Production taxes		6.9	%		6.7	%		+3	%		5.9	%		6.9	%		- 14	%

~~In response to the current macro-economic environment, reduced planned 2020 capital expenditures and shutting in certain marginal wells, we anticipate decreases in~~ LOE and gathering, processing and transportation ~~of approximately 10% during~~costs decreased in the ~~remainder of 2020.~~second quarter due to the challenged macro-economic environment which resulted in lower activity levels. Additionally, ~~we expect lower~~ production taxes ~~as a result of~~decreased due to lower oil, gas and NGL ~~revenues.~~sales.

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 ~~revenues~~sales less production expenses and is not prepared in accordance with GAAP. A reconciliation to the comparable GAAP measures is found in “Non-GAAP Measures” in this Item 2. The changes in production volumes, field prices and production expenses, shown above, had the following impact on our field-level cash margins by asset.

	Q1 2020		$ per BOE		Q4 2019		$ per BOE		Q2 2020		$ per BOE		Q1 2020		$ per BOE
Field-level cash margin (non-GAAP)
Delaware Basin	$	260	$	17.72	$	372	$	26.30	$	106	$	7.81	$	260	$	17.72
Anadarko Basin		74	$	8.22		147	$	15.06
Powder River Basin		54	$	20.48		73	$	28.86		20	$	9.09		54	$	20.48
Eagle Ford		87	$	19.20		98	$	23.72		22	$	4.50		87	$	19.20
Anadarko Basin										13	$	1.67		74	$	8.22
Other		14	$	15.55		21	$	22.33		—	$	0.10		14	$	15.55
Total	$	489	$	15.41	$	711	$	22.55	$	161	$	5.45	$	489	$	15.41

Due to lower commodity benchmark prices, our unhedged realized price per Boe dropped 44% from the first quarter to the second quarter of 2020. These lower realizations dramatically reduced our field-level cash margin and other performance measures. Consequently, we have initiatives underway to reduce annualized expenses $300 million by the end of 2020. These initiatives include decreasing annualized production expenses $125 million and general and administrative expenses $100 million. These savings will be generated from adjustments to our workforce and production operations, as well as expiries of minimum volume commitments. We also intend to reduce net financing costs $75 million upon repurchasing up to $1.5 billion of debt as authorized by our Board of Directors.

	Q1 2020			Q4 2019			Change in earnings			Q2 2020			Q1 2020			Change in earnings
Commodity hedge valuation changes ⁽¹⁾	$	619		$	(158	)	$	777		$	(593	)	$	619		$	(1,212	)
Marketing and midstream operations		(18	)		5			(23	)		(8	)		(18	)		10
Exploration expenses		112			29			(83	)		12			112			100
Net financing costs		65			64			(1	)		69			65			(4	)
Restructuring and transaction costs		—			11			11
Other expenses		(48	)		16			64			13			(48	)		(61	)
							$	745								$	(1,167	)

~~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.~~

Our first quarter 2020 net loss from continuing operations was $1.7 billion. The graph below shows the change in net loss from the first quarter of 2019 to the first quarter of 2020. The material changes are further discussed on the following pages. To facilitate the review, these numbers are being presented before consideration of earnings attributable to noncontrolling interests.

~~Production Volumes~~

Q1 2020

% of Total

Q1 2019

Change

Oil (MBbls/d)

Delaware Basin

84

51
%

60

+40
%
Anadarko Basin

24

15
%

32

- 27
%
Powder River Basin

21

13
%

15

+39
%
Eagle Ford

26

16
%

25

+6
%
Other

8

5
%

9

- 13
%
Total

163

100
%

141

+15
%

Q1 2020

% of Total

Q1 2019

Change

Gas (MMcf/d)

Delaware Basin

244

38
%

146

+68
%
Anadarko Basin

272

43
%

333

- 18
%
Powder River Basin

29

4
%

18

+56
%
Eagle Ford

86

14
%

83

+3
%
Other

3

1
%

8

- 58
%
Total

634

100
%

588

+8
%

Q1 2020

% of Total

Q1 2019

Change

NGLs (MBbls/d)

Delaware Basin

37

47
%

23

+62
%
Anadarko Basin

30

37
%

35

- 17
%
Powder River Basin

3

4
%

2

+44
%
Eagle Ford

9

11
%

12

- 21
%
Other

1

1
%

2

- 32
%
Total

80

100
%

74

+9
%

Q1 2020

% of Total

Q1 2019

Change

Combined (MBoe/d)

Delaware Basin

162

47
%

107

+51
%
Anadarko Basin

98

28
%

123

- 20
%
Powder River Basin

29

8
%

21

+41
%
Eagle Ford

50

14
%

50

- 1
%
Other

9

3
%

12

- 22
%
Total

348

100
%

313

+11
%

An increase in production volumes from the first quarter of 2019 to the first quarter of 2020 contributed to a $133 million increase in earnings. Continued development in the Delaware Basin and Powder River Basin drove production increases, which were slightly offset by decreased activity in the Anadarko Basin.

~~Field Prices~~

Q1 2020

Realization

Q1 2019

Change

Oil (per Bbl)

WTI index

$
46.44

$
54.88

- 15
%
Realized price, unhedged

$
44.59

96%

$
51.83

- 14
%
Cash settlements

$
5.14

$
3.65

Realized price, with hedges

$
49.73

107%

$
55.48

- 10
%

Q1 2020

Realization

Q1 2019

Change

Gas (per Mcf)

Henry Hub index

$
1.95

$
3.15

- 38
%
Realized price, unhedged

$
1.21

62%

$
2.62

- 54
%
Cash settlements

$
0.36

$
(0.31
)

Realized price, with hedges

$
1.57

81%

$
2.31

- 32
%

Q1 2020

Realization

Q1 2019

Change

NGLs (per Bbl)

Mont Belvieu blended index ⁽¹⁾

$
14.39

$
22.94

- 37
%
Realized price, unhedged

$
10.40

72%

$
18.36

- 43
%
Cash settlements

$
0.61

$
0.67

Realized price, with hedges

$
11.01

77%

$
19.03

- 42
%

~~(1)~~

~~Based upon composition of our~~ NGL ~~barrel.~~

Q1 2020

Q1 2019

Change

Combined (per Boe)

Realized price, unhedged

$
25.43

$
32.65

- 22
%
Cash settlements

$
3.20

$
1.22

Realized price, with hedges

$
28.63

$
33.87

- 15
%

~~From the first quarter of 2019 to the first quarter of 2020, field prices contributed to a $245 million decrease in earnings.~~ Unhedged realized oil, gas and NGL prices decreased primarily due to lower WTI, Henry Hub and Mont Belvieu index prices. These decreases were partially offset by favorable hedge cash settlements across each of our products.

~~Hedge Settlements~~

Q1 2020

Q1 2019

Change

Q

Oil

$
76

$
46

+65
%
Natural gas

21

(16
)

+231
%
NGL

4

4

+0
%
Total cash settlements

$
101

$
34

+197
%

~~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 2020

Q1 2019

Change

LOE

$
126

$
110

+15
%
Gathering, processing & transportation

130

109

+19
%
Production taxes

56

60

- 7
%
Property taxes

6

4

+50
%
Total

$
318

$
283

+12
%
Per Boe:

LOE

$
3.96

$
3.95

+0
%
Gathering, processing &
transportation

$
4.11

$
3.86

+6
%
Percent of oil, gas and NGL sales:

Production taxes

6.9
%

6.5
%

+6
%

~~LOE and gathering, processing and transportation increased~~ ~~primarily due to continued development and increased activity in the Delaware Basin.~~

~~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 revenues less production expenses and is not prepared in accordance with GAAP. A reconciliation to the comparable GAAP measures is found in “Non-GAAP Measures” in this Item 2. The changes in production volumes, field prices and production expenses, shown above, had the following impact on our field-level cash margins by asset.

Q1 2020

$ per BOE

Q1 2019

$ per BOE

Field-level cash margin (non-GAAP)

Delaware Basin

$
260

$
17.72

$
235

$
24.39

Anadarko Basin

74

$
8.22

203

$
18.27

Powder River Basin

54

$
20.48

50

$
27.02

Eagle Ford

87

$
19.20

128

$
28.53

Other

14

$
15.55

19

$
17.57

Total

$
489

$
15.41

$
635

$
22.54

~~DD&A and Asset Impairments~~

Q1 2020

Q1 2019

Change

Oil and gas per Boe

$
11.90

$
11.73

+1
%

Oil and gas

$
377

$
331

+14
%
Other property and equipment

24

29

- 19
%
Total

$
401

$
360

+11
%

Asset impairments

$
2,666

$
—

N/M

~~Our oil and gas DD&A increased primarily due to continued development in the Delaware Basin and Powder River Basin properties.~~

Asset impairments were $2.7 billion in the first quarter of 2020 due to significant decreases in commodity prices since the end of 2019 resulting primarily from the COVID-19 pandemic. For additional information, see ~~Note 5~~ ~~in “Part I. Financial Information – Item 1. Financial Statements” in this report.~~

~~General and Administrative Expenses~~

Q1 2020

Q1 2019

Change

Labor and benefits (net of reimbursements)

$
66

$
86

- 23
%
Non-labor

36

49

- 27
%
Total Devon

$
102

$
135

- 24
%

~~Labor and benefits and non-labor expenses decreased primarily as a result of continued workforce reduction and cost savings initiatives.~~

~~Other Items~~

Q1 2020

Q1 2019

Change in earnings

Commodity hedge valuation changes ⁽¹⁾

$
619

$
(639
)

$
1,258

Marketing and midstream operations

(18
)

15

(33
)
Exploration expenses

112

4

(108
)
Asset dispositions

—

(45
)

(45
)
Net financing costs

65

60

(5
)
Restructuring and transaction costs

—

51

51

Other expenses

(48
)

(22
)

26

$
1,144

~~(1)~~

~~Included as a component of upstream revenues~~derivatives on the consolidated statements of comprehensive earnings.

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

Marketing and midstream operations improved primarily due to downstream product inventory impairments of $17 million recognized in the first quarter of 2020.

Exploration expenses decreased due to $110 million of unproved asset impairments during the first quarter of 2020. For additional information, see Note 5 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

Our second quarter 2020 net loss from continuing operations was $677 million, compared to net earnings of $151 million in the second quarter of 2019. The graph below shows the change in net earnings (loss) from the second quarter of 2019 to the second quarter of 2020. The material changes are further discussed on the following pages.

Our six months ended June 30, 2020 net loss from continuing operations was $2.4 billion, compared to a net loss of $227 million for the six months ended June 30, 2019. The graph below shows the change in the net loss from the six months ended June 30, 2019 to the six months ended June 30, 2020. The material changes are further discussed on the following pages.

	Three Months Ended June 30,										Six Months Ended June 30,
	2020		% of Total			2019		Change			2020		% of Total			2019		Change
Oil (MBbls/d)
Delaware Basin		79		52	%		67		+19	%		81		51	%		63		+29	%
Powder River Basin		18		12	%		15		+20	%		20		13	%		15		+30	%
Eagle Ford		27		18	%		23		+16	%		27		17	%		24		+11	%
Anadarko Basin		21		13	%		31		- 32	%		22		14	%		32		- 30	%
Other		8		5	%		8		- 1	%		8		5	%		9		- 8	%
Total		153		100	%		144		+6	%		158		100	%		143		+11	%
Gas (MMcf/d)
Delaware Basin		241		39	%		158		+52	%		242		39	%		152		+60	%
Powder River Basin		20		3	%		22		- 7	%		24		4	%		20		+21	%
Eagle Ford		87		14	%		81		+8	%		87		14	%		82		+6	%
Anadarko Basin		262		43	%		313		- 16	%		267		43	%		323		- 17	%
Other		4		1	%		4		+0	%		4		0	%		6		- 38	%
Total		614		100	%		578		+6	%		624		100	%		583		+7	%
NGLs (MBbls/d)
Delaware Basin		29		42	%		27		+8	%		33		45	%		25		+33	%
Powder River Basin		2		3	%		2		+20	%		3		3	%		2		+32	%
Eagle Ford		12		17	%		12		- 7	%		10		14	%		12		- 13	%
Anadarko Basin		25		37	%		40		- 37	%		28		37	%		38		- 27	%
Other		1		1	%		1		- 40	%		1		1	%		1		- 35	%
Total		69		100	%		82		- 15	%		75		100	%		78		- 5	%
Combined (MBoe/d)
Delaware Basin		149		46	%		120		+24	%		155		46	%		113		+37	%
Powder River Basin		24		7	%		21		+15	%		27		8	%		21		+28	%
Eagle Ford		53		16	%		49		+8	%		52		15	%		50		+3	%
Anadarko Basin		90		28	%		124		- 27	%		94		28	%		123		- 24	%
Other		9		3	%		10		- 9	%		9		3	%		11		- 15	%
Total		325		100	%		324		+0	%		337		100	%		318		+6	%

From the second quarter of 2019 to the second quarter of 2020, an increase in higher-margin oil volumes contributed to a $34 million increase in earnings. From the six months ended 2019 to the six months ended 2020, an increase in volumes contributed to a $166 million increase in earnings. Continued development in the Delaware Basin and Powder River Basin has resulted in higher production volumes during 2020 compared to 2019. These increases were partially offset by significantly lower activity in the Anadarko Basin.

	Three Months Ended June 30,									Six Months Ended June 30,
	2020		Realization	2019			Change			2020		Realization	2019		Change
Oil (per Bbl)
WTI index	$	28.42		$	59.85			- 53	%	$	37.43		$	57.36		- 35	%
Realized price, unhedged	$	21.25	75%	$	57.11			- 63	%	$	33.27	89%	$	54.51		- 39	%
Cash settlements	$	15.25		$	(0.41	)				$	10.04		$	1.59
Realized price, with hedges	$	36.50	128%	$	56.70			- 36	%	$	43.31	116%	$	56.10		- 23	%
Gas (per Mcf)
Henry Hub index	$	1.71		$	2.64			- 35	%	$	1.83		$	2.90		- 37	%
Realized price, unhedged	$	1.29	76%	$	1.38			- 6	%	$	1.25	68%	$	2.00		- 38	%
Cash settlements	$	0.28		$	0.34					$	0.32		$	0.02
Realized price, with hedges	$	1.57	92%	$	1.72			- 9	%	$	1.57	86%	$	2.02		- 22	%
NGLs (per Bbl)
Mont Belvieu blended index ⁽¹⁾	$	12.57		$	19.05			- 34	%	$	13.48		$	21.00		- 36	%
Realized price, unhedged	$	8.89	71%	$	15.00			- 41	%	$	9.70	72%	$	16.57		- 41	%
Cash settlements	$	0.51		$	1.40					$	0.56		$	1.06
Realized price, with hedges	$	9.40	75%	$	16.40			- 43	%	$	10.26	76%	$	17.63		- 42	%
Combined (per Boe)
Realized price, unhedged	$	14.37		$	31.79			- 55	%	$	20.09		$	32.21		- 38	%
Cash settlements	$	7.83		$	0.79					$	5.43		$	1.00
Total	$	22.20		$	32.58			- 32	%	$	25.52		$	33.21		- 23	%

From the second quarter of 2019 to the second quarter of 2020, field prices contributed to a $546 million decrease in earnings. From the six months ended 2019 to the six months ended 2020, field prices contributed to a $790 million decrease in earnings. Unhedged realized oil, gas and NGL prices decreased primarily due to lower WTI, Henry Hub and Mont Belvieu index prices. These decreases were partially offset by favorable hedge cash settlements across each of our products.

An increase in gathering, processing and transportation costs from the six months ended 2019 to the six months ended 2020 was due to higher volumes and the Anadarko minimum volume commitments which are set to expire at the end of 2020. These increases were offset by lower production taxes resulting from lower oil, gas and NGL sales.

The changes in production volumes, field prices and production expenses, shown above, had the following impact on our field-level cash margins by asset.

DD&A decreased primarily due to lower rates resulting from asset impairments recorded in the first quarter of 2020.

Labor and benefits and non-labor expenses decreased primarily as a result of continued workforce reduction and cost savings initiatives.

Marketing and midstream operations decreased approximately ~~$33~~$58 million for the first six months ended 2020 compared to the first six months ended 2019 primarily due to lower commodity prices resulting from the challenged macro-economic environment in 2020, as well as downstream product inventory impairments of $17 million recognized in the first quarter of 2020.

Exploration expenses increased inapproximately $113 million for the first six months ended 2020 compared to the first six months ended 2019 primarily due to ~~$110~~$113 million in unproved asset ~~impairments.~~impairments in the first six months of 2020. For additional information, see Note 5 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

Devon recognized $63 million in restructuring expenses during the first six months of 2019 due to workforce reductions and other initiatives designed to enhance its operational focus and cost structure. For ~~discussion on income taxes,~~additional information, see Note 76 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

The table below presents key components from discontinued operations for the time periods presented. Discontinued operations include the Canadian business that Devon sold in June 2019 and the Barnett Shale assets that Devon has contracted to sell and which is ~~expected~~scheduled to close on ~~December 31,~~October 1, 2020. For additional information on discontinued operations, see Note 17 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

	Q1 2020			Q4 2019			Q1 2019		Three Months Ended									Six Months Ended
Upstream revenues	$	92		$	121		$	396
									June 30,			March 31,			June 30,			June 30,			June 30,
									2020			2020			2019			2020			2019
Oil, gas and NGL sales									$	77		$	92		$	494		$	169		$	994
Oil, gas and NGL derivatives									$	—		$	—		$	9		$	—		$	(95	)
Production expenses	$	74		$	75		$	222	$	74		$	74		$	229		$	148		$	451
Marketing margin	$	—		$	—		$	17
Asset impairments	$	179		$	748		$	—	$	—		$	179		$	37		$	179		$	37
Asset dispositions									$	(2	)	$	—		$	(188	)	$	(2	)	$	(187	)
Restructuring and transaction costs	$	—		$	4		$	3	$	—		$	—		$	236		$	—		$	239
Earnings (loss) from discontinued operations before income taxes	$	(157	)	$	(724	)	$	70	$	9		$	(157	)	$	62		$	(148	)	$	132
Income tax expense (benefit)	$	(32	)	$	(72	)	$	9
Income tax benefit									$	—		$	(32	)	$	(282	)	$	(32	)	$	(273	)
Net earnings (loss) from discontinued operations, net of tax	$	(125	)	$	(652	)	$	61	$	9		$	(125	)	$	344		$	(116	)	$	405

Production (MMBoe):
Barnett Shale		9			9			9		9			9			9			18			18
Canada		—			—			10		—			—			9			—			19
Total production		9			9			19		9			9			18			18			37
Realized price, unhedged (per Boe) - Barnett Shale	$	10.16		$	13.45		$	16.18	$	8.89		$	10.16		$	12.57		$	9.54		$	14.38
Realized price, unhedged (per Boe) - Canada	N/A			N/A			$	34.42	N/A			N/A			$	43.03		N/A			$	38.41

Net ~~loss~~earnings (loss) from discontinued operations, net of tax ~~decreased $527~~increased $134 million ~~due to a decrease in asset impairments~~ from ~~the fourth quarter of 2019 to~~ the first quarter of ~~2020.~~2020 to the second quarter of 2020. During the first quarter of 2020, we recognized $179 million in asset impairments on our Barnett Shale assets due to the amended terms of the Barnett Shale sales agreement. ~~During~~This increase in earnings was partially offset by lower gas and NGL sales in the ~~fourth~~second quarter resulting from lower commodity prices.

Net earnings from discontinued operations, net of tax decreased $335 million from the second quarter of 2019 ~~we recognized a $748 million asset impairment~~ to ~~our Barnett Shale assets.~~the second quarter of 2020. Net earnings decreased primarily due to the divestment of Devon’s Canadian operations during the second quarter of 2019.

Net earnings (loss) from discontinued operations, net of tax decreased ~~$186~~$521 million for the first six months ended June 30, 2020 compared to the first six months ended June 30, 2019. Net earnings decreased primarily due to the divestment of Devon’s Canadian operations during the second quarter of 2019, as well as lower revenues resulting from the challenged macro-economic environment in 2020. Additionally, 2020 includes $179 million in incremental asset impairments to our Barnett Shale assets related to the amended terms of the Barnett Shale sales agreement during the first quarter of 2020. ~~Upstream revenues and production expenses decreased from the first quarter of 2019 to the first quarter of 2020 due to Devon’s divestment of its Canadian business in the second quarter of 2019.~~

The following table presents the major changes in cash and cash equivalents for the three and six months ended ~~March 31,~~June 30, 2020 and 2019.

	Three Months Ended March 31st,						Three Months Ended June 30,						Six Months Ended June 30,
	2020			2019			2020			2019			2020			2019
Operating cash flow from continuing operations	$	529		$	437		$	150		$	432		$	679		$	868
Divestitures of property and equipment		25			310			3			28			28			338
Capital expenditures		(425	)		(490	)		(307	)		(486	)		(732	)		(976	)
Acquisitions of property and equipment		(4	)		(10	)		(1	)		(13	)		(5	)		(23	)
Debt activity, net		—			(162	)		—			—			—			(162	)
Repurchases of common stock		(38	)		(999	)		—			(187	)		(38	)		(1,185	)
Common stock dividends		(34	)		(34	)		(42	)		(37	)		(76	)		(71	)
Contributions from noncontrolling interests		5			—			6			—			11			—
Distributions to noncontrolling interests		(3	)		—			(3	)		—			(6	)		—
Other		(17	)		(19	)		—			(3	)		(17	)		(23	)
Net change in cash, cash equivalents and restricted cash from discontinued operations		(155	)		(124	)		136			2,764			(19	)		2,641
Net change in cash, cash equivalents and restricted cash	$	(117	)	$	(1,091	)	$	(58	)	$	2,498		$	(175	)	$	1,407
Cash, cash equivalents and restricted cash at end of period	$	1,727		$	1,355		$	1,669		$	3,853		$	1,669		$	3,853

Despite our portfolio enhancements, aggressive cost reductions and operational advancements, our financial results were challenged by commodity prices and deterioration of the macro-economic environment resulting from the unprecedented COVID-19 pandemic. As presented in the table above, net cash provided by operating activities continued to be a significant source of capital and liquidity. During the ~~three~~six months ended ~~March 31,~~June 30, 2020, our operating cash flow funded ~~all~~approximately 85% of our capital expenditures and ~~dividends, allowing us to use available cash balances to fund other capital uses.~~dividends.

During the first ~~three~~six months of 2019, we sold non-core U.S. assets for approximately ~~$300~~$338 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 31st,				Three Months Ended June 30,				Six Months Ended June 30,
	2020		2019		2020		2019		2020		2019
Delaware Basin	$	221	$	225	$	192	$	245	$	413	$	470
Powder River Basin		85		56		46		60		131		116
Eagle Ford		94		55		42		54		136		109
Anadarko Basin		8		136		10		93		18		229
Other		3		11		3		15		6		26
Total oil and gas		411		483		293		467		704		950
Midstream		8		—		11		11		19		11
Other		6		7		3		8		9		15
Total capital expenditures	$	425	$	490	$	307	$	486	$	732	$	976
Acquisitions	$	4	$	10	$	1	$	13	$	5	$	23

Capital expenditures consist primarily of amounts related to our oil and gas exploration and development operations, midstream operations and other corporate activities. Our capital program is designed to operate within or near operating cash flow. This is evidenced by our operating cash flow ~~fully~~ funding approximately 90% of our capital expenditures for the ~~three~~six months ended ~~March 31, 2020 and 89% of~~

~~capital expenditures for the three months ended March 31, 2019.~~June 30, 2020. Our capital investment program is driven by a disciplined allocation process focused on returns. Our capital expenditures are lower in 2020 primarily due to our decreased spending in the Anadarko Basin, partially offset by increased capital investment in the Powder River Basin and Eagle Ford. In response to the current macro-economic environment, we reduced our 2020 capital expenditures outlook by approximately $800 million, or 45% compared to the original capital ~~budget, and expect to fund our 2020 capital program within operating cash flows even at current depressed commodity prices.~~budget.

During the first ~~quarter~~six months of 2019, our debt decreased $162 million due to the repayment of our 6.30% senior notes at maturity.

~~We paid~~The following table summarizes our common stock dividends ~~of $34 million ($0.09 per share) and $34 million ($0.08 per share)~~ during the first ~~three~~six months of 2020 and ~~2019, respectively. In February 2020, we announced a 22% increase to our quarterly dividend, to $0.11 per share, beginning in the second quarter of 2020.~~2019. Beginning with the second quarter of ~~2019,~~2020, we increased our quarterly dividend 22%, to $0.11 per share. We previously increased our quarterly dividend to $0.09 per ~~share.~~share commencing with the second quarter of 2019.

We repurchased 2.2 million shares of common stock for $38 million in the first ~~three~~six months of 2020 and ~~36.1~~42.1 million shares of common stock for ~~$1.0~~$1.2 billion in the first ~~three~~six months of 2019 under share repurchase programs authorized by our Board of Directors. For additional information, see Note 16 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

During the first ~~quarter~~six months of 2020, we received $5$11 million in contributions from our noncontrolling interests in CDM and distributed $3$6 million to our noncontrolling interests in CDM.

All cash flows in the following table relate to activities of our Canadian business that Devon sold in June 2019 and the Barnett Shale assets that Devon has contracted to sell and is ~~expected~~scheduled to close ~~in the fourth quarter of~~on October 1, 2020.

	Three Months Ended March 31st,						Three Months Ended June 30,						Six Months Ended June 30,
	2020			2019			2020			2019			2020			2019
Canadian tax payments	$	(153	)	$	—		$	(20	)	$	—		$	(173	)	$	—
Settlements of intercompany foreign denominated assets/liabilities								—			(32	)		—			(31	)
Other		22			(59	)		(23	)		223			(1	)		162
Operating activities		(131	)		(59	)		(43	)		191			(174	)		131
Divestitures of property and equipment - Canadian operations								—			2,601			—			2,601
Divestitures of property and equipment - Barnett Shale assets								170			—			170			—
Divestitures of property and equipment								170			2,601			170			2,601
Capital expenditures and other								1			(65	)		—			(123	)
Investing activities		(1	)		(59	)		171			2,536			170			2,478
Financing activities		—			(7	)		—			—			—			(7	)
Settlements of intercompany foreign denominated assets/liabilities								—			32			—			31
Other								8			5			(15	)		8
Effect of exchange rate changes on cash		(23	)		1			8			37			(15	)		39
Net change in cash, cash equivalents and restricted cash of discontinued operations	$	(155	)	$	(124	)	$	136		$	2,764		$	(19	)	$	2,641

Operating cash flows induring the first ~~quarter~~six months of 2020 include ~~$153~~$173 million of cash income and withholding tax payments in Canada related to ~~divestitures. Additionally, operating cash flow~~divestitures and was also negatively ~~affected~~impacted by lower commodity prices. Foreign currency denominated intercompany loan activity resulted in a realized loss of $32 million in the ~~first~~second quarter of 2019 ~~primarily~~as a result of the strengthening of the U.S. dollar in relation to the Canadian dollar. There was an offset in the effect of exchange rate changes on cash line in the table above, resulting in no impact to the net change in cash, cash equivalents and restricted cash. Investing cash flows during the first six months of 2020 include $170 million in deposit funds from BKV due to ~~realization impacts associated with~~ the ~~widening~~amended terms on the sale of our Barnett Shale assets, which is scheduled to close on October 1, 2020. On June 27, 2019, we completed the sale of our Canadian ~~differentials in the fourth quarter~~business for proceeds of ~~2018.~~$2.6 billion. See Note 2 and Note 17 in “Part I. Financial Information – Item 1. Financial Statements” in this report for additional details on these divestitures.

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.

Historically, our primary sources of capital funding and liquidity have been our operating cash flow, cash on hand and asset divestiture proceeds. Additionally, we maintain a commercial paper program, supported by our revolving line of credit, which can be

accessed as needed to supplement operating cash flow and cash balances. If needed, we can also issue debt and equity securities, including through transactions under our shelf registration statement filed with the SEC. We estimate the combination of our sources of capital will continue to be adequate to fund our planned capital requirements as discussed in this section.

Beginning in the first quarter of 2020, the macro-economic environment ~~has~~ deteriorated significantly and has created extreme volatility primarily due to concerns arising from the COVID-19 pandemic. In response to this environment, we will continue to maintain flexibility within our capital program as we continue to focus on protecting our financial strength and maintaining operational continuity. Additionally, we have initiatives underway to reduce annualized production, administrative and financing expenses a total of $300 million. Further, we expect to fund a $0.26 per share (approximately $100 million total) special dividend on October 1, 2020.

Key inputs into determining our planned capital investment are the amounts 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 2020, we held approximately $1.7 billion of cash, inclusive of ~~$200~~$195 million of cash restricted for discontinued operations. Our operating cash flow forecasts are sensitive to many variables and include a measure of uncertainty as the actual results of 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 substantially variable factors influence market conditions for these products. These factors, which are difficult to predict, create volatility in prices and are beyond our control.

Actions taken by governments around the world in response to the COVID-19 pandemic have led to an unprecedented decline in global oil demand. Oil prices, which had already been trending down on concerns about oversupply, subsequently collapsed in March. Benchmark WTI spot oil prices fell from over $60/Bbl in early January to less than $20/Bbl in April.

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. For the remainder of 2020, we have approximately ~~90%~~95% of our oil production hedged with an average floor price of ~~$42/~~$41/Bbl and approximately 45% of our gas production hedged with an average floor price of ~~$2.15/~~$2.20/Mcf. Additionally, we are currently building our 2021 hedge positions at market prices. The key terms to our oil, gas and NGL derivative financial instruments as of ~~March 31,~~June 30, 2020 are presented in Note 3 in “Part I. Financial Information – Item 1. Financial Statements” of this report.

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.

Driven by lower realized prices, margins and capital investment, we have begun initiatives to reduce our annualized production and administrative costs a total of $225 million. We expect these annualized savings to be sustainable as we tailor our workforce and operations for current activity levels.

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 and other protections allowed per our agreements.

~~In April 2020, we amended the terms on the sale of~~We expect to close our Barnett Shale ~~assets with an expected close date of December 31,~~divestiture on October 1, 2020. ~~Under the terms of the agreement, we received the deposit funds of $170 million in April 2020. The deposit is being held by us pursuant~~Pursuant to the terms of ~~the sale agreement, which only requires us~~this transaction, we currently hold a $170 million deposit and expect to ~~return such funds to BKV in the event the transaction does not close as a result~~receive approximately $300 million at closing, net of ~~our breach of our closing obligations.~~purchase price adjustments.

In response to the current macro-economic environment, we reduced our 2020 capital expenditures outlook by approximately $800 million, or 45% compared to the original capital ~~budget, and expect to fund our 2020 capital program within operating cash flows, even at current depressed commodity prices.~~budget. Our exploration and development budget for the remainder of 2020 is expected to range from ~~$0.6 billion~~$350 million to ~~$0.7 billion.~~$400 million. As economic factors change, we will continue to be flexible with our capital program.

Our Board of Directors has authorized a $1.5 billion debt repurchase program. Repurchases will be dependent on market conditions and may be made through open market purchases, tender offers or other transaction structures. The repurchases are expected to generate $75 million of annualized financing cost savings.

As of ~~March 31,~~June 30, 2020, 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, 2020, 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 negative outlook. Our credit rating from Fitch is BBB with a stable outlook. Our credit rating from Moody’s Investor Service is Ba1 with a stable outlook. Any rating downgrades may result in additional letters of credit or cash collateral being posted under certain contractual arrangements.

In December 2019, our Board of Directors approved a $1.0 billion share repurchase program that expires on December 31, 2020. Through March 31, 2020, we had executed $38 million of the authorized program. However, as the pricing and economic environment has deteriorated due to the COVID-19 pandemic and demand challenges for commodities, we have temporarily suspended our share repurchase program to preserve liquidity. Additionally, due to the amended terms of our Barnett Shale divestiture, we do not anticipate being able to purchase more than $200 million of the $1.0 billion authorization by the program expiration date. We will monitor economic conditions as they develop and may resume share repurchases of the remaining $162 million, subject to the commodity price environment, the Company’s liquidity and capital resources and other factors.

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 to an unprecedented downturn in the commodity price environment and the resulting asset impairments, Devon had significant deferred tax assets at March 31, 2020. Accordingly, we ~~have~~ reassessed the realizability of our deferred tax assets in future periods and ~~have~~ recorded a 100% valuation allowance against our net deferred tax ~~assets.~~assets during the first quarter of 2020. As of June 30, 2020, we remain in a full valuation allowance position.

Long-lived assets used in operations, including proved and unproved oil and gas properties, are depreciated and assessed for impairment annually or whenever changes in facts and circumstances indicate a possible significant deterioration in future cash flows is expected to be generated by an asset group. For DD&A calculations and impairment assessments, management groups individual assets based on a judgmental assessment of the lowest level (“common operating field”) for which there are identifiable cash flows that are largely independent of the cash flows of other groups of assets.

Management evaluates assets for impairment through an established process in which changes to significant assumptions such as prices, volumes and future development plans are reviewed. If, upon review, the sum of the undiscounted pre-tax cash flows is less than the carrying value of the asset group, the carrying value is written down to estimated fair value. Because there usually is a lack of quoted market prices for long-lived assets, the fair value of impaired assets is typically determined based on the present values of expected future cash flows using discount rates believed to be consistent with those used by principal market participants. The expected future cash flows used for impairment reviews and related fair value calculations are typically based on judgmental assessments of future production volumes, commodity prices, operating costs and capital investment plans, considering all available information at the date of review. The expected future cash flows used for impairment reviews include future production volumes associated with proved producing and risk-adjusted proved undeveloped, probable and possible reserves.

Besides the risk-adjusted estimates of reserves and future production volumes, future commodity prices are the largest driver in the variability of undiscounted pre-tax cash flows. For our impairment determinations, we historically have utilized NYMEX forward

strip prices for the first five years and applied internally generated price forecasts for subsequent years. In response to the COVID-19 pandemic, the NYMEX forward market became highly illiquid as evidenced by materially reduced trading volumes for periods beyond 2021. Therefore, we altered our price forecast assumptions to perform our March 31, 2020 impairment computations. Specifically, we supplemented the NYMEX forward strip prices with price forecasts published by reputable investment banks and reservoir engineering firms to estimate our future revenues as of March 31, 2020.

We also estimate and escalate or de-escalate future capital and operating costs by using a method that correlates cost movements to price movements similar to recent history. To measure indicated impairments, we use a market-based weighted-average cost of

capital to discount the future net cash flows. Changes to any of the reserves or market-based assumptions can significantly ~~effect~~affect estimates of undiscounted and discounted pre-tax cash flows and impact the recognition and amount of impairments.

Reduced demand from the COVID-19 pandemic and management of production levels from ~~Saudi Arabia and Russia~~OPEC caused WTI pricing to decrease more than 60% during the first quarter of 2020. As a result, we reduced our planned 2020 capital investment 45%. With materially lower commodity prices and reduced near-term investment, we assessed all our oil and gas fields for impairment as of March 31, 2020 and recognized proved and unproved impairments totaling $2.8 billion. The impairments relate to our Anadarko Basin and Rockies fields in which our basis included acquisitions completed in 2016 and 2015, respectively, when commodity prices were much higher than they are today.

~~Based on~~We assessed our ~~March 31,~~Eagle Ford asset for impairment as of June 30, 2020 utilizing the same methodology we applied for the impairment ~~evaluations,~~assessments for all of our and oil and gas fields in the first quarter of 2020. Our Eagle Ford asset’s sum of undiscounted ~~pre-tax~~ cash flows ~~exceeds~~exceeded the carrying value ~~by less than 10%. This~~indicating no impairment as of June 30, 2020. Further, as a result of improved oil pricing, the cushion ~~narrowed~~increased significantly ~~since the end of 2019 due~~from March 31, 2020 to ~~lower benchmark pricing and wider differentials used to estimate future commodity pricing.~~ IfJune 30, 2020. If prices significantly deteriorate ~~further~~ and/or management ~~significantly reduces~~lowers the planned capital investment in the Eagle Ford field, our Eagle Ford asset could be subject to a material impairment of capitalized costs.

We test goodwill for impairment annually at October 31, or more frequently if events or changes in circumstances dictate that the carrying value of goodwill may not be recoverable. We perform a qualitative assessment to determine whether it is more likely than not that the fair value of goodwill is less than its carrying amount. As part of our qualitative assessment, we considered the general macro-economic, industry and market conditions, changes in cost factors, actual and expected financial performance, significant changes in management, strategy or customers and stock performance. If the qualitative assessment determines that a quantitative goodwill impairment test is required, then the fair value is compared to the carrying value. If the fair value is less than the carrying value, an impairment charge will be recognized for the amount by which the carrying amount exceeds the fair value. Because quoted market prices are not available, the fair value is estimated based upon a valuation analyses including comparable companies and transactions and premiums paid.

Because the trading price of our common stock decreased 73% during the first quarter of 2020 in response to the COVID-19 pandemic, we performed a goodwill impairment test as of March 31, 2020. While the cushion narrowed significantly since our last impairment evaluation, we concluded an impairment was not required as of March 31, 2020. The two most critical judgements included in the March 31, 2020, test were the period utilized to determine Devon’s market capitalization and the control premium. For the test performed as of March 31, 2020 we derived our market capitalization by using our average common stock price from the latter two thirds of March 2020, to align with the time in the quarter subsequent to a key OPEC+ meeting and the date COVID-19 was officially classified as a pandemic. We applied a control premium based on recent comparable market transactions.

Subsequent to the end of the first quarter of 2020, Devon’s common stock price increased approximately ~~80%~~60% during the ~~month of April~~second quarter but remains significantly less than our average trading price before the events experienced in the first quarter of 2020. Although our common stock price and commodity prices are in a period of high volatility, a sustained period of depressed commodity prices would adversely affect our estimates of future operating results, which could result in future goodwill impairments due to the potential impact on the cash flows of our operations. The impairment of goodwill has no effect on liquidity or capital resources. However, it would adversely affect our results of operations in the period recognized.

For additional information regarding our critical accounting policies and estimates, see our 2019 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 2020 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 noncash and other items that are typically excluded by securities analysts in their published estimates of our financial results. For more information on the results of discontinued operations for our Barnett Shale asset and Canadian operations, see Note 17 in “Part I. Financial Information – Item 1. Financial Statements” in this report. Our non-GAAP measures are typically used as a quarterly performance measure. Amounts excluded relate to asset dispositions, noncash asset impairments (including noncash unproved asset impairments), deferred tax asset valuation allowance, fair value changes in derivative financial instruments and foreign currency, changes in tax legislation and restructuring and transaction costs associated with the workforce reductions in 2019.

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 our core earnings and core earnings per share attributable to Devon to their 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
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	)		—			—			—			(0.00	)		—			(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	)
2019
Continuing Operations
Loss attributable to Devon (GAAP)	$	(497	)	$	(378	)	$	(378	)	$	(0.89	)
Earnings (loss) attributable to Devon (GAAP)													$	219		$	151		$	151		$	0.37		$	(278	)	$	(227	)	$	(227	)	$	(0.54	)
Adjustments:
Asset dispositions		(45	)		(35	)		(35	)		(0.08	)		(2	)		(1	)		(1	)		(0.00	)		(47	)		(36	)		(36	)		(0.08	)
Asset and exploration impairments		1			1			1			0.00			1			1			1			0.00			2			2			2			0.00
Deferred tax asset valuation allowance		—			(13	)		(13	)		(0.03	)		—			11			11			0.03			—			(2	)		(2	)		(0.01	)
Fair value changes in financial instruments		638			492			492			1.15			(117	)		(90	)		(90	)		(0.22	)		521			402			402			0.95
Restructuring and transaction costs		51			39			39			0.09			12			10			10			0.02			63			49			49			0.12
Core earnings attributable to Devon (Non-GAAP)	$	148		$	106		$	106		$	0.24		$	113		$	82		$	82		$	0.20		$	261		$	188		$	188		$	0.44
Discontinued Operations
Loss attributable to Devon (GAAP)	$	70		$	61		$	61		$	0.15
Earnings attributable to Devon (GAAP)													$	62		$	344		$	344		$	0.82		$	132		$	405		$	405		$	0.96
Adjustments:
Asset dispositions		1			1			1			0.00			(188	)		(460	)		(460	)		(1.12	)		(187	)		(459	)		(459	)		(1.10	)
Asset and exploration impairments														38			27			27			0.07			38			27			27			0.07
Deferred tax asset valuation allowance		—			(5	)		(5	)		(0.01	)		—			32			32			0.08			—			27			27			0.06
Fair value changes in financial instruments and foreign currency and other		(3	)		(8	)		(8	)		(0.03	)		(20	)		(17	)		(17	)		(0.04	)		(23	)		(24	)		(24	)		(0.06	)
Restructuring and transaction costs		3			3			3			0.01			236			172			172			0.42			239			175			175			0.42
Core earnings attributable to Devon (Non-GAAP)	$	71		$	52		$	52		$	0.12		$	128		$	98		$	98		$	0.23		$	199		$	151		$	151		$	0.35
Total
Loss attributable to Devon (GAAP)	$	(427	)	$	(317	)	$	(317	)	$	(0.74	)
Earnings (loss) attributable to Devon (GAAP)													$	281		$	495		$	495		$	1.19		$	(146	)	$	178		$	178		$	0.42
Adjustments:
Continuing Operations		645			484			484			1.13			(106	)		(69	)		(69	)		(0.17	)		539			415			415			0.98
Discontinued Operations		1			(9	)		(9	)		(0.03	)		66			(246	)		(246	)		(0.59	)		67			(254	)		(254	)		(0.61	)
Core earnings attributable to Devon (Non-GAAP)	$	219		$	158		$	158		$	0.36		$	241		$	180		$	180		$	0.43		$	460		$	339		$	339		$	0.79

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 ~~revenues~~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,
	2020			2019			2020			2019			2020			2019
Net loss (GAAP)	$	(1,815	)	$	(317	)
Net earnings (loss) (GAAP)							$	(668	)	$	495		$	(2,483	)	$	178
Net (earnings) loss from discontinued operations, net of tax		125			(61	)		(9	)		(344	)		116			(405	)
Financing costs, net		65			60			69			66			134			126
Income tax benefit		(417	)		(119	)
Income tax expense (benefit)								(3	)		68			(420	)		(51	)
Exploration expenses		112			4			12			7			124			11
Depreciation, depletion and amortization		401			360			299			374			700			734
Asset impairments		2,666			—			—			—			2,666			—
Asset dispositions		—			(45	)		—			(2	)		—			(47	)
Share-based compensation		20			23			19			21			39			44
Derivative and financial instrument non-cash valuation changes		(619	)		638			593			(117	)		(26	)		521
Restructuring and transaction costs		—			51			—			12			—			63
Accretion on discounted liabilities and other		(48	)		(22	)		13			8			(35	)		(14	)
EBITDAX (non-GAAP)		490			572			325			588			815			1,160
Marketing and midstream revenues and expenses, net		18			(15	)		8			(17	)		26			(32	)
Commodity derivative cash settlements		(101	)		(34	)		(232	)		(23	)		(333	)		(57	)
General and administration expenses, cash-based		82			112
General and administrative expenses, cash-based								60			93			142			205
Field-level cash margin (non-GAAP)	$	489		$	635		$	161		$	641		$	650		$	1,276

As of ~~March 31,~~June 30, 2020, we have commodity derivatives that pertain to a portion of our estimated production for the last ~~nine~~six months of 2020, as well as for 2021. 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, 2020, a 10% change in the forward curves associated with our commodity derivative instruments would have changed our net positions by approximately ~~$140~~$165 million.

As of ~~March 31,~~June 30, 2020, we had total debt of $4.3 billion. All of our debt is based on fixed interest rates averaging 6.0%.

Devon has certain Canadian dollar obligations associated with its divested Canadian operations which are to be paid with the cash restricted for discontinued operations. These balances are remeasured using the applicable exchange rate as of the end of the reporting period. A 10% unfavorable change in the Canadian-to-U.S. dollar exchange rate would not have materially impacted our ~~March 31,~~June 30, 2020 balance sheet for these items. See Note 17 in “Part I. Financial Information – Item 1. Financial Statements” in this report for additional information.

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, 2020 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.

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

We are involved in various legal proceedings incidental to our business. However, to our knowledge as of the date of this report, there were no material pending legal proceedings to which we are a party or to which any of our property is subject.

Except for the addition of the pandemic risk factor discussed ~~below,~~in our Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2020, there have been no material changes to the information included in Item 1A. “Risk Factors” in our 2019 Annual Report on Form 10-K.

~~Our Business Has Been Adversely Impacted by the COVID-19 Pandemic, and We May Experience Continuing or Worsening Adverse Effects From This or Other Pandemics~~

~~Commodity Price Impacts –~~ The COVID-19 pandemic and related economic repercussions have created significant volatility, uncertainty and turmoil in the oil and gas industry. This outbreak and the related responses of governmental authorities and others to limit the spread of the virus have significantly reduced global economic activity, resulting in an unprecedented decline in the demand for oil and other commodities. This supply-and-demand imbalance has been exacerbated by uncertainty regarding the future global supply of oil due to disputes between Russia and the members of OPEC, particularly Saudi Arabia. These factors caused a swift and material deterioration in commodity prices in early 2020, with NYMEX WTI oil prices falling from over $60/Bbl at the beginning of the year to lower than $20/Bbl as of April 2020. While OPEC and other oil producing nations agreed in April 2020 to cut production, downward pressure on commodity prices has remained and could continue for the foreseeable future. This decline in commodity prices has already adversely impacted our results of operations for the first quarter of 2020 and contributed to our recognition of a material asset impairment to our oil and gas assets during the same period. As further described in the “Risk Factors” section of our ~~2019 Annual Report on Form 10-K, any sustained weakness or further deterioration in commodity prices could further adversely impact our results of operations, the value of our properties and our financial condition.~~

The current supply-and-demand imbalance has also imposed constraints on Devon’s and other operators’ ability to store and move production to downstream markets, which has resulted in the delay or curtailment of development activity, as well as the shutting-in of producing wells. Moreover, certain regional prices have disproportionally declined relative to broader market indices in areas that have experienced acute takeaway capacity constraints, thereby potentially further reducing our realized pricing in such impacted areas. If we are forced to shut in additional production, we will likely incur greater costs to bring the associated production back online, and such costs may be significant enough that such wells may become non-economic at low commodity price levels, which may lead to decreases in our proved reserve estimates and potential impairments and associated charges to our earnings. If we are able to bring wells back online, there is no assurance that such wells will be as productive following recommencement as they were prior to being shut in.

~~General Financial and Economic Impacts~~ - The negative effects of COVID-19 on economic prospects across the world have contributed to concerns for the potential of a prolonged economic slowdown and recession. Any such downturn, or a protracted period of depressed commodity prices, could have significant adverse consequences for our financial condition and liquidity, by, among other things: (i) limiting our ability to access sources of capital due to disruptions in financial markets or otherwise; and (ii) increasing the risk of a downgrade from credit rating agencies, which could trigger new credit support obligations and further adversely affect our ability to access financing or trade credit. Moreover, any such downturn could also result in similar financial constraints for our non-operating partners, purchasers of our production and other counterparties, thereby increasing the risk that such counterparties default on their obligations to us. Such defaults or more general supply chain disruptions due to the pandemic may also jeopardize the supply of materials, equipment or services for our operations. For additional information regarding liquidity and counterparty credit risks, please see the “Risk Factors” section of the ~~2019 Annual Report on Form 10-K~~.

~~Other Impacts -~~ The COVID-19 pandemic and related restrictions aimed at mitigating its spread have caused us to modify certain of our business practices, including limiting employee travel, encouraging work-from-home practices and other social distancing measures. Such measures may cause disruptions to our business and operational plans, which may include shortages of employees, contractors and subcontractors. There is no certainty that these or any other future measures will be sufficient to mitigate the risks posed by the disease, including the risk of infection of key employees, and our ability to perform certain functions could be impaired by these new business practices. For example, our reliance on technology has necessarily increased due to our encouragement of remote communications and other work-from-home practices, which could make us more vulnerable to cyber attacks. See the “Risk Factors” section of the ~~2019 Annual Report on Form 10-K~~ ~~for additional information regarding cyber attack risks.~~

The COVID-19 pandemic and its related effects continue to rapidly evolve. The ultimate extent of the impact of the COVID-19 pandemic and any other future pandemic on our business will depend on future developments, including, but not limited to, the nature, duration and spread of the disease, the responsive actions to contain its spread or address its effects and the duration, timing and severity of the related consequences on commodity prices and the economy more generally, including any recession resulting from the pandemic. Any extended period of depressed commodity prices or general economic disruption as a result of the pandemic would adversely affect our business, financial condition and results of operations. In addition, the COVID-19 pandemic has heightened, and any future pandemic could heighten, the other risks and uncertainties discussed in the “Risk Factors” section of the ~~2019 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 2020 (shares in thousands).

Under the Devon Plan, eligible employees made purchases of shares of our common stock through an investment in the Devon Stock Fund, which is administered by an independent trustee. Eligible employees purchased approximately ~~5,800~~4,100 shares of our common stock in the ~~first~~second quarter of 2020, at then-prevailing stock prices, that they held through their ownership in the Stock Fund. We acquired the shares of our common stock sold under the Devon Plan through open-market purchases.

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 – Divestitures	11
	Note 3 – Derivative Financial Instruments	11
	Note 4 – Share-Based Compensation	1413
	Note 5 – Asset Impairments	1514
	Note 6 – Restructuring and Transaction Costs	15
	Note 7 – Income Taxes	16
	Note 8 – Net Earnings (Loss) Per Share From Continuing Operations	17
	Note 9 – Other Comprehensive Earnings (Loss)	17
	Note 10 – Supplemental Information to Statements of Cash Flows	18
	Note 11 – Accounts Receivable	18
	Note 12 – Property, Plant and Equipment	18
	Note 13 – Debt and Related Expenses	19
	Note 14 – Leases	19
	Note 15 – Asset Retirement Obligations	20
	Note 16 – Stockholders’ Equity	20
	Note 17 – Discontinued Operations and Assets Held For Sale	21
	Note 18 – Commitments and Contingencies	23
	Note 19 – Fair Value Measurements	24
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	25
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	4246
Item 4.	Controls and Procedures	4246

Part II. Other Information
Item 1.	Legal Proceedings	4347
Item 1A.	Risk Factors	4347
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	4447
Item 3.	Defaults Upon Senior Securities	4447
Item 4.	Mine Safety Disclosures	4447
Item 5.	Other Information	4447
Item 6.	Exhibits	4548

Signatures		4649

	Oil Basis Swaps
Period	Index	Volume (Bbls/d)		Weighted Average Differential to WTI ($/Bbl)
Q2-Q4 2020	Argus MEH		50,916	$	0.45
Q2-Q4 2020	Midland Sweet		31,782	$	(1.23	)
Q2-Q4 2020	NYMEX Roll		52,676	$	0.38
Q1-Q4 2021	Midland Sweet		7,000	$	1.27

	Oil Basis Swaps
Period	Index	Volume (Bbls/d)		Weighted Average Differential to WTI ($/Bbl)
Q3-Q4 2020	Argus MEH		52,500	$	0.42
Q3-Q4 2020	Midland Sweet		32,000	$	(1.23	)
Q3-Q4 2020	NYMEX Roll		54,000	$	0.38
Q1-Q4 2021	Midland Sweet		7,000	$	1.27


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

	Natural Gas Basis Swaps
Period	Index	Volume (MMBtu/d)		Weighted Average Differential to Henry Hub ($/MMBtu)
Q2-Q4 2020	Panhandle Eastern Pipe Line		30,000	$	(0.47	)
Q2-Q4 2020	El Paso Natural Gas		65,000	$	(0.78	)
Q2-Q4 2020	Houston Ship Channel		30,000	$	(0.02	)
Q1-Q4 2021	El Paso Natural Gas		35,000	$	(0.92	)

		Price Swaps
Period	Product	Volume (Bbls/d)		Weighted Average Price ($/Bbl)
Q2-Q4 2020	Ethane		9,982	$	5.62
Q2-Q4 2020	Natural Gasoline		1,000	$	44.84
Q2-Q4 2020	Normal Butane		1,500	$	23.56
Q2-Q4 2020	Propane		4,500	$	25.18

	2020
Grant-date fair value	$	27.89
Risk-free interest rate	1.36%
Volatility factor	38.4%
Contractual term (years)	2.89

	Other			Other
	Current			Long-term
	Liabilities			Liabilities			Total
	(Millions)
Balance as of December 31, 2019	$	20		$	1		$	21
Changes related to prior years' restructurings		(13	)		—			(13	)
Balance as of June 30, 2020	$	7		$	1		$	8

Balance as of December 31, 2018	$	39		$	3		$	42
Changes related to prior years' restructurings		—			(2	)		(2	)
Balance as of June 30, 2019	$	39		$	1		$	40

	Total Number of Shares Purchased		Dollar Value of Shares Purchased		Average Price Paid per Share
$5.0 Billion Plan
Full year 2018		78,149	$	2,978	$	38.11
First quarter 2019		36,141		1,024		28.33
Second quarter 2019		5,911		159		27.01
Third quarter 2019		22,137		550		24.80
Fourth quarter 2019		4,436		94		21.32
Total inception-to-date		146,774	$	4,805	$	32.74

$1.0 Billion Plan
First quarter 2020		2,243	$	38	$	16.85
Total inception-to-date		2,243	$	38	$	16.85

	Amounts		Rate Per Share
Quarter Ended 2020:
First quarter	$	34	$	0.09
Second quarter		42	$	0.11
Total year-to-date	$	76
Quarter Ended 2019:
First quarter	$	34	$	0.08
Second quarter		37	$	0.09
Total year-to-date	$	71

	Q1 2020			Q4 2019
Current benefit	$	(106	)	$	(5	)
Deferred benefit		(311	)		(28	)
Total benefit	$	(417	)	$	(33	)
Effective income tax rate		20	%		155	%

Period	Total Number of Shares Purchased ⁽¹⁾		Average Price Paid per Share		Total Number of Shares Purchased As Part of Publicly Announced Plans or Programs ⁽²⁾		Maximum Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs ⁽²⁾
January 1 - January 31		18	$	24.99		—	$	1,000
February 1 - February 29		2,175	$	18.71		1,568	$	973
March 1 - March 31		830	$	16.01		675	$	962
Total		3,023	$	18.00		2,243

Exhibit Number		Description

2.1		First Amendment to Purchase and Sale Agreement, dated April 13, 2020, by and between Devon Energy Production Company, L.P., BKV Barnett, LLC, and solely with respect to certain provisions therein, BKV Oil & Gas Capital Partners, L.P. (incorporated by reference to Exhibit 2.1 to Registrant’s Form 8-K filed April 14, 2020; File No. 001-32318).

10.1*		2020 Form of Notice of Grant of Restricted Stock Award and Award Agreement under the 2017 Long-Term Incentive Plan between ~~Devon Energy Corporation~~Registrant and ~~certain officers~~all non-management directors for restricted stock ~~awarded (CEO and EVP form).~~

10.2*		2020 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 (CEO and EVP form).

10.3*		2020 Form of Notice of Grant of Restricted Stock Award and Award Agreement under the 2017 Long-Term Incentive Plan between Devon Energy Corporation and certain officers for restricted stock awarded (SVP form).

10.4*		2020 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 (SVP form).awarded.

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

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

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

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

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

101.SCH		Inline XBRL Taxonomy Extension Schema Document.

101.CAL		Inline XBRL Taxonomy Extension Calculation Linkbase Document.

101.DEF		Inline XBRL Taxonomy Extension Definition Linkbase Document.

101.LAB		Inline XBRL Taxonomy Extension Labels Linkbase Document.

101.PRE		Inline XBRL Taxonomy Extension Presentation Linkbase Document.

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

				DEVON ENERGY CORPORATION

Date: ~~May 6,~~August 5, 2020				/s/ Jeremy D. Humphers
				Jeremy D. Humphers
				Senior Vice President and Chief Accounting Officer