dvn-10k_20201231.htm

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

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes ☐ No ☒

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, a 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 has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. ☑

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act). Yes ☐ No ☒

The aggregate market value of the voting common stock held by non-affiliates of the registrant as of June 30, 2020 was approximately $4.3 billion, based upon the closing price of $11.34 per share as reported by the New York Stock Exchange on such date. On February 3, 2021, 673.1 million shares of common stock were outstanding.

Portions of Registrant’s definitive Proxy Statement relating to Registrant’s 2020 annual meeting of stockholders have been incorporated by reference in Part III of this Annual Report on Form 10-K.

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 Annual Report on Form 10-K:

“2015 Plan” means the Devon Energy Corporation 2015 Long-Term Incentive Plan.

“2017 Plan” means the Devon Energy Corporation 2017 Long-Term Incentive Plan.

“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. Bitumen and 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. All dollar amounts associated with Canada are in U.S. dollars, unless stated otherwise.

“Federal Funds Rate” means the interest rate at which depository institutions lend balances at the Federal Reserve to other depository institutions overnight.

“General Partner” means EnLink Midstream, LLC, the indirect general partner entity of EnLink, and, unless the context otherwise indicates, EnLink Midstream Manager, LLC, the managing member of EnLink Midstream, LLC.

“Inside FERC” refers to the publication Inside F.E.R.C.’s Gas Market Report.

“Merger” means the merger of Merger Sub with and into WPX, with WPX continuing as the surviving corporation and a wholly-owned subsidiary of the Company, pursuant to the terms of the Merger Agreement.

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

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

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

“Standardized measure” means the present value of after-tax future net revenues discounted at 10% per annum.

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

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

A Delaware corporation formed in 1971 and publicly held since 1988, Devon (NYSE: DVN) is an independent energy company engaged primarily in the exploration, development and production of oil, natural gas and NGLs. Our operations are concentrated in various onshore areas in the U.S. In October 2020, we completed the sale of our Barnett Shale assets.

On January 7, 2021, Devon and WPX completed an all-stock merger of equals. WPX is an oil and gas exploration and production company with assets in the Delaware Basin in Texas and New Mexico and the Williston Basin in North Dakota. This merger enhances the scale of our operations, builds a leading position in the Delaware Basin and accelerates our cash-return business model that prioritizes free cash flow generation and the return of capital to shareholders. In accordance with the Merger Agreement, WPX shareholders received a fixed exchange of 0.5165 shares of Devon common stock for each share of WPX common stock owned. The combined company continues to operate under the name Devon. Our principal and administrative offices are located at 333 West Sheridan, Oklahoma City, OK 73102-5015 (telephone 405-235-3611).

Devon files or furnishes annual reports on Form 10-K, quarterly reports on Form 10-Q and current reports on Form 8-K, as well as any amendments to these reports, with the SEC. Through our website, www.devonenergy.com, we make available electronic copies of the documents we file or furnish to the SEC, the charters of the committees of our Board of Directors and other documents related to our corporate governance. The corporate governance documents available on our website include our Code of Ethics for Chief Executive Officer, Chief Financial Officer and Chief Accounting Officer, and any amendments to and waivers from any provision of that Code will also be posted on our website. Access to these electronic filings is available free of charge as soon as reasonably practicable after filing or furnishing them to the SEC. Printed copies of our committee charters or other governance documents and filings can be requested by writing to our corporate secretary at the address on the cover of this report. Reports filed with the SEC are also made available on its website at www.sec.gov.

Our business strategy is focused on delivering a consistently competitive shareholder return among our peer group. Because the business of exploring for, developing and producing oil and natural gas is capital intensive, delivering sustainable, capital efficient cash flow growth is a key tenant to our success. While our cash flow is highly dependent on volatile and uncertain commodity prices, we pursue our strategy throughout all commodity price cycles with four fundamental principles.

Proven and responsible operator – We operate our business with the interests of our stakeholders and our environmental, social and governance values in mind. With our vision to be a premier independent oil and natural gas exploration and production company, the work our employees do every day contributes to the local, national and global economies. We produce a valuable commodity that is fundamental to society, and we endeavor to do so in a safe, environmentally responsible and ethical way, while striving to deliver strong returns to our shareholders. We have an ongoing commitment to transparency in reporting our environmental, social and governance performance. See our Sustainability Report published on our company website for performance highlights and additional information. Information contained in our Sustainability Report is not incorporated by reference into, and does not constitute a part of, this Annual Report on Form 10-K.

Premier, sustainable portfolio of assets – As discussed later in this section of this Annual Report, we own a portfolio of assets located in the United States. We strive to own premier assets capable of generating cash flows in excess of our capital and operating requirements, as well as competitive rates of return. We also desire to own a portfolio of assets that can provide sustainable production extending many years into the future. Due to the strength of oil prices relative to natural gas, we have positioned our portfolio to be more heavily weighted to U.S. oil assets in recent years.

During 2019, we sold our Canadian business, generating $2.6 billion in proceeds. During 2020, we sold our Barnett Shale assets, generating proceeds of $490 million and 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. On January 7, 2021, Devon and WPX completed an all-stock merger of equals. WPX is an oil and gas exploration and production company with assets in the Delaware Basin in Texas and New Mexico and the Williston Basin in North Dakota. As a result of these transactions, our oil production, price realizations and field-level margins will all improve, as we sharpen our focus on five U.S. oil and liquids plays located in the Delaware Basin, Powder River Basin, Anadarko Basin, Williston Basin and Eagle Ford.

Superior execution – As we pursue cash flow growth, we continually work to optimize the efficiency of our capital programs and production operations, with an underlying objective of reducing absolute and per unit costs and enhancing our returns. We also strive to leverage our culture of health, safety and environmental stewardship in all aspects of our business.

With the WPX Merger and continuous improvement initiatives, we are building a scalable, multi-basin portfolio of U.S. oil assets and aggressively improving our cost structure to further expand margins. We have realized annualized cost savings by reducing well costs, production expense, financing costs and G&A costs.

Financial strength and flexibility – Commodity prices are uncertain and volatile, so we strive to maintain a strong balance sheet, as well as adequate liquidity and financial flexibility, in order to operate competitively in all commodity price cycles. Our capital allocation decisions are made with attention to these financial stewardship principles, as well as the priorities of funding our core operations, protecting our investment-grade credit ratings, and paying and growing our shareholder dividend.

Delivering strong operational and financial results in a safe, environmentally and socially responsible way requires the expertise and positive contributions of every Devon employee. Consequently, our people are the Company’s most important resource and we seek to hire the best people who share our core values of doing the right thing, delivering results and being good team members and neighbors to our communities. To develop our workforce, we focus on training, safety, wellness, inclusion, diversity and equality. As of December 31, 2020, Devon and its consolidated subsidiaries had approximately 1,400 employees, all located in the U.S.

We prepare our workforce to work safely with comprehensive training and orientation, on-the-job guidance and tools, safety engagements, recognition and other resources. Employees and contractors are expected to comply with safety rules and regulations and are accountable to stopping at-risk work, immediately reporting incidents and near-miss events and informing visitors of emergency alarms and evacuation plans. To safeguard workers on our well sites and neighbors nearby, we plan, design, drill, complete and produce wells using proven best practices, technologies, tools and materials.

In response to the COVID-19 pandemic, we have developed and implemented a number of safety measures to help our employees manage their work and personal responsibilities, with a strong focus on employee well-being, health and safety. Refer to “COVID-19” included in Item 7. “Management’s Discussion and Analysis of Financial Condition and Results of Operations” for information on actions taken by Devon to protect and support its employees during the COVID-19 pandemic.

Beyond employee safety, Devon also prioritizes the physical, mental and financial wellness of our employees. We offer competitive health and financial benefits with incentives designed to promote wellbeing. For example, we encourage employees to take advantage of our wellness programs and activities by getting an annual physical exam or completing a financial wellness series at no cost to employees.

We strive to attract and retain high-performing individuals across our workforce. One way we do this is by providing competitive compensation and benefits, including annual bonuses; a 401(k) savings plan with a Devon match; stock awards; medical, dental and vision health care coverage; health savings and dependent-care flexible spending accounts; maternity and parental leave for the birth or adoption of a child; an adoption assistance program; alternate work schedules; flexible work hours; part-time work options; telecommuting support; among other benefits.

Devon also looks to our core values to build the workforce we need. We develop our employees’ knowledge and creativity and advance continual learning and career development through ongoing performance, training and development conversations.

Devon’s success depends on employees who demonstrate integrity, accountability, perseverance and a passion for building our business and delivering results. Our efforts to create a workforce with these qualities start with offering equal opportunity in all aspects of employment. We do this with employee-led organizations and corporate policies.

We promote inclusion and diversity throughout the Company to bring a range of thoughts, experiences and points of view to our problem-solving and decision-making processes. Devon has an Inclusion and Diversity Leadership Team, which consists of senior leaders who support others by coaching, motivating and breaking down barriers. The Inclusion and Diversity Leadership Team works together with Devon’s all-volunteer Inclusion Action Team to proactively increase diversity and inclusion awareness, identify challenges and find innovative ways to achieve Devon’s inclusion and diversity vision and strategy.

All Devon employees must act in accordance with our Code of Business Conduct and Ethics (“Code”), which sets forth current business practices and guidance to ensure ongoing compliance. Our Code covers topics such as anti-corruption, harassment, discrimination, privacy, cybersecurity, confidential information and how to report Code violations. On an annual basis, Devon employees are required to acknowledge and agree to abide by our Code, as well as complete a training course on the Code and its related policies. Additionally, our directors, officers and employees are required to comply with policies such as our Zero Tolerance Anti-Harassment Policy, Anti-Corruption Policy and Procedure, Conflicts of Interest Policy and Employee Gifts and Entertainment Declaration Policy.

Additional information regarding Devon’s human capital measures and objectives is contained in Devon’s Sustainability Report published on our company website. Information contained in our Sustainability Report is not incorporated by reference into, and does not constitute a part of, this Annual Report on Form 10-K.

On January 7, 2021, Devon and WPX completed an all-stock merger of equals. WPX is an oil and gas exploration and production company with assets in the Delaware Basin in Texas and New Mexico and the Williston Basin in North Dakota. Financial and operational data, such as reserves, production, wells and acreage, provided in this document exclude amounts related to WPX’s assets unless otherwise noted due to the Merger closing subsequent to December 31, 2020. For additional information, please see Note 2 in “Item 8. Financial Statements and Supplementary Data” of this report.

As a result of our divestment of substantially all of our oil and gas assets and operations in Canada, as well as the divestiture of our Barnett Shale assets, amounts associated with these assets are presented as discontinued operations. The financial and operational data, such as reserves, production, wells and acreage, provided in this document exclude amounts related to our Canadian and Barnett Shale assets unless otherwise noted. Included within the amounts presented as discontinued operations associated with the Barnett Shale are properties divested in previous reporting periods located primarily in Johnson and Wise counties, Texas. For additional information, please see Note 2 in “Item 8. Financial Statements and Supplementary Data” of this report.

Key summary data from each of our areas of operation as of and for the year ended December 31, 2020 are detailed in the map below.

Delaware Basin – The Delaware Basin is Devon’s most active program in the portfolio. Through capital-efficient drilling programs, it offers exploration and low-risk development opportunities from many geologic reservoirs and play types, including the oil-rich Wolfcamp, Bone Spring, Leonard and Delaware formations. With a significant inventory of oil and liquids-rich drilling opportunities that have multi-zone development potential, Devon has a robust platform to deliver high-margin drilling programs for many years to come. At December 31, 2020, we had eight operated rigs developing this asset in the Wolfcamp and Bone Spring formations. Combined with the Delaware Basin assets acquired in the WPX merger, we plan to invest approximately $1.5 billion of capital in the Delaware Basin in 2021, making it the top-funded asset in the portfolio.

Powder River Basin – This asset is focused on emerging oil opportunities in the Powder River Basin. Devon is currently targeting several Cretaceous oil objectives, including the Turner, Parkman, Teapot and Niobrara formations. Recent drilling success in this basin has expanded our drilling inventory, and we expect further growth as we accelerate activity and continue to de-risk this emerging light-oil opportunity. Devon has several uncompleted wells in its Powder River Basin inventory and has resumed capital activity in early 2021. In 2021, we plan approximately $80 million of capital investment.

Eagle Ford – We acquired our position in the Eagle Ford in 2014. Since acquiring these assets, we have delivered tremendous results driven by our development in DeWitt County, Texas located in the economic core of the play. Our Eagle Ford production is leveraged to oil and has low-cost access to premium Gulf Coast pricing, providing for solid operating margins. As a result of the COVID-19 pandemic and related significant decrease to oil pricing in early 2020, Devon did not pursue any drilling and completion

activity in the latter half of 2020 for these assets. Devon has several uncompleted wells in its Eagle Ford inventory and has resumed capital activity in early 2021. In 2021, we plan approximately $110 million of capital investment.

Anadarko Basin – Our Anadarko Basin development, located primarily in Oklahoma’s Canadian, Kingfisher and Blaine counties, provides long-term optionality through its significant inventory. Our Anadarko Basin position is one of the largest in the industry, providing visible long-term production. At the end of 2019, we announced an agreement with Dow to jointly develop a portion of our Anadarko Basin acreage. This joint venture activity was delayed in response to the challenged macro-economic environment resulting from the COVID pandemic. However, due to improvements in natural gas pricing, the joint venture has commenced in the first quarter of 2021 with a two operated rig program. Dow will fund approximately 65% of the partnership capital requirements through a drilling carry of $100 million over the next four years. In 2021, we plan approximately $75 million of capital investment, net to Devon.

Proved oil and gas reserves are those quantities of oil, gas and NGLs which can be estimated with reasonable certainty to be economically producible from known reservoirs under existing economic conditions, operating methods and government regulations. To be considered proved, oil and gas reserves must be economically producible before contracts providing the right to operate expire, unless evidence indicates that renewal is reasonably certain. Also, the project to extract the hydrocarbons must have commenced or the operator must be reasonably certain that it will commence the project within a reasonable time. We establish our proved reserves estimates using standard geological and engineering technologies and computational methods, which are generally accepted by the petroleum industry. We primarily prepare our proved reserves additions by analogy using type curves that are based on decline curve analysis of wells in analogous reservoirs. We further establish reasonable certainty of our proved reserves estimates by using one or more of the following methods: geological and geophysical information to establish reservoir continuity between penetrations, rate-transient analysis, analytical and numerical simulations, or other proprietary technical and statistical methods. For estimates of our proved developed and proved undeveloped reserves and the discussion of the contribution by each property, see Note 22 in “Item 8. Financial Statements and Supplementary Data” of this report.

The process of estimating oil, gas and NGL reserves is complex and requires significant judgment, as discussed in “Item 1A. Risk Factors” of this report. As a result, we have developed internal policies for estimating and recording reserves in compliance with applicable SEC definitions and guidance. Our policies assign responsibilities for compliance in reserves bookings to our Reserve Evaluation Group (the “Group”). The Group, which is led by Devon’s Director of Reserves and Economics, is responsible for the internal review and certification of reserves estimates. We ensure the Director and key members of the Group have appropriate technical qualifications to oversee the preparation of reserves estimates and are independent of the operating groups. The Director of the Group has over 30 years of industry experience, a degree in engineering and is a registered professional engineer. The Group also oversees audits and reserves estimates performed by qualified third-party petroleum consulting firms. During 2020, we engaged LaRoche Petroleum Consultants, Ltd. to audit approximately 88% of our proved reserves. Additionally, we have a Reserves Committee that provides additional oversight of our reserves process. The committee consists of five independent members of our Board of Directors with education or business backgrounds relevant to the reserves estimation process.

The following tables present production, price and cost information for each significant field in our asset portfolio and the total company.

	Production
Year Ended December 31,	Oil (MMBbls)		Gas (Bcf)		NGLs (MMBbls)		Total (MMBoe)
2020
Anadarko Basin		7		92		10		33
Delaware Basin		31		91		13		60
Total		57		221		29		122
2019
Anadarko Basin		11		114		13		43
Delaware Basin		26		65		10		46
Total		55		219		28		119
2018
Anadarko Basin		12		121		14		45
Delaware Basin		16		42		6		30
Total		47		206		26		108

	Average Sales Price
Year Ended December 31,	Oil (Per Bbl)		Gas (Per Mcf)		NGLs (Per Bbl)		Production Cost (Per Boe) ⁽¹⁾
2020
Anadarko Basin ⁽²⁾	$	35.80	$	1.66	$	12.11	$	9.61
Delaware Basin	$	37.25	$	1.08	$	10.64	$	5.76
Total	$	35.95	$	1.48	$	11.72	$	7.66
2019
Anadarko Basin	$	55.13	$	1.97	$	15.90	$	7.36
Delaware Basin	$	54.01	$	0.99	$	13.54	$	6.43
Total	$	54.73	$	1.79	$	15.21	$	7.75
2018
Anadarko Basin	$	63.81	$	2.29	$	25.53	$	7.16
Delaware Basin	$	57.24	$	1.80	$	24.05	$	8.15
Total	$	61.96	$	2.34	$	25.47	$	8.22

The following table summarizes our development and exploratory drilling results.

	Development Wells⁽¹⁾				Exploratory Wells ⁽¹⁾				Total Wells ⁽¹⁾
Year Ended December 31,	Productive		Dry		Productive		Dry		Productive		Dry		Total
2020		106.5		—		26.6		—		133.2		—		133.2
2019		161.7		—		27.2		—		188.9		—		188.9
2018		154.9		3.1		69.4		—		224.3		3.1		227.4

As of December 31, 2020, there were 156 gross and 77.6 net wells that have been spud and are in the process of drilling, completing or waiting on completion. To effectively manage capital expenditures and provide flexibility in managing drilling rig and well completion schedules, we have a large inventory of drilled but not completed wells. Gross wells are the sum of all wells in which we own a working interest. Net wells are gross wells multiplied by our fractional working interests in each well.

Oil Wells

Natural Gas Wells

Total Wells

Gross⁽¹⁾⁽³⁾

Net⁽²⁾

Gross⁽¹⁾⁽³⁾

Net⁽²⁾

Gross⁽¹⁾⁽³⁾

Net⁽²⁾

Total

7,752

2,385

2,980

1,201

10,732

3,586

The day-to-day operations of oil and gas properties are the responsibility of an operator designated under pooling or operating agreements. The operator supervises production, maintains production records, employs field personnel and performs other functions. We are the operator of approximately 3,942 gross wells. As operator, we receive reimbursement for direct expenses incurred to perform our duties, as well as monthly per-well producing, drilling, and construction overhead reimbursement at rates customarily charged in the respective areas. In presenting our financial data, we record the monthly overhead reimbursements as a reduction of G&A, which is a common industry practice.

The following table sets forth our developed and undeveloped lease and mineral acreage as of December 31, 2020. Of our 1.8 million net acres, approximately 1.0 million acres are held by production. The acreage in the table includes approximately 0.1 million net acres subject to leases that are scheduled to expire during 2021, 2022 and 2023. Of the 0.1 million net acres set to expire by December 31, 2023, we anticipate performing operational and administrative actions to continue the lease terms for portions of the acreage that we intend to further assess. However, we do expect to allow a portion of the acreage to expire in the normal course of business. Subsequent to our merger with WPX, less than 20% of our total net acres are located on federal lands.

Developed

Undeveloped

Total

Gross⁽¹⁾

Net⁽²⁾

Gross⁽¹⁾

Net⁽²⁾

Gross⁽¹⁾

Net⁽²⁾

(Thousands)

Total

953

504

2,994

1,267

3,947

1,771

Title to properties is subject to contractual arrangements customary in the oil and gas industry, liens for taxes not yet due and, in some instances, other encumbrances. We believe that such burdens do not materially detract from the value of properties or from the respective interests therein or materially interfere with their use in the operation of the business.

As is customary in the industry, a preliminary title investigation, typically consisting of a review of local title records, is made at the time of acquisitions of undeveloped properties. More thorough title investigations, which generally include a review of title records and the preparation of title opinions by outside legal counsel, are made prior to the consummation of an acquisition of producing properties and before commencement of drilling operations on undeveloped properties.

The spot markets for oil, gas and NGLs are subject to volatility as supply and demand factors fluctuate. As detailed below, we sell our production under both long-term (one year or more) and short-term (less than one year) agreements at prices negotiated with third parties. Regardless of the term of the contract, the vast majority of our production is sold at variable, or market-sensitive, prices.

Additionally, we may enter into financial hedging arrangements or fixed-price contracts associated with a portion of our oil, gas and NGL production. These activities are intended to support targeted price levels and to manage our exposure to price fluctuations. See Note 3 in “Item 8. Financial Statements and Supplementary Data” of this report for further information.


	Short-Term						Long-Term
	Variable			Fixed			Variable			Fixed
Oil		45	%		5	%		50	%		—
Natural gas		56	%		3	%		41	%		—
NGLs		63	%		25	%		12	%		—

A portion of our production is sold under certain contractual arrangements that specify the delivery of a fixed and determinable quantity. As of December 31, 2020, we were committed to deliver the following fixed quantities of production.

	Total		Less Than 1 Year		1-3 Years		3-5 Years		More Than 5 Years
Natural gas (Bcf)		174		90		52		32		—
NGLs (MMBbls)		7		7		—		—		—
Total (MMBoe)		36		22		9		5		—

We expect to fulfill our delivery commitments primarily with production from our proved developed reserves. Moreover, our proved reserves have generally been sufficient to satisfy our delivery commitments during the three most recent years, and we expect such reserves will continue to be the primary means of fulfilling our future commitments. However, where our proved reserves are not sufficient to satisfy our delivery commitments, we can and may use spot market purchases to satisfy the commitments.

Our industry is subject to a wide range of regulations. Laws, rules, regulations, taxes, fees and other policy implementation actions affecting our industry have been pervasive and are under constant review for amendment or expansion. Numerous government agencies have issued extensive regulations which are binding on our industry and its individual members, some of which carry substantial penalties for failure to comply. These laws and regulations increase the cost of doing business and consequently affect profitability. Because public policy changes are commonplace, and existing laws and regulations are frequently amended, we are unable to predict the future cost or impact of compliance. However, we do not expect that any of these laws and regulations will affect our operations materially differently than they would affect other companies with similar operations, size and financial strength. The following are significant areas of government control and regulation affecting our operations.

Our operations are subject to federal, state and local laws and regulations. These laws and regulations relate to matters that include:

Our operations also are subject to conservation regulations, including the regulation of the size of drilling and spacing units or proration units; the number of wells that may be drilled in a unit; the rate of production allowable from oil and gas wells; and the unitization or pooling of oil and gas properties. In the U.S., some states allow the forced pooling or unitization of tracts to facilitate exploration, while other states rely on voluntary pooling of lands and leases, which may make it more difficult to develop oil and gas properties. In addition, federal and state conservation laws generally limit the venting or flaring of natural gas, and state conservation laws impose certain requirements regarding the ratable purchase of production. These regulations limit the amounts of oil and gas we can produce from our wells and the number of wells or the locations at which we can drill.

Certain of our U.S. natural gas and oil leases are granted or approved by the federal government and administered by the BLM or Bureau of Indian Affairs of the Department of the Interior. Such leases require compliance with detailed federal regulations and orders that regulate, among other matters, drilling and operations on lands covered by these leases and calculation and disbursement of royalty payments to the federal government, tribes or tribal members. Moreover, the permitting process for oil and gas activities on federal lands can sometimes be subject to delay, which can stall development activities or otherwise adversely impact operations. The federal government has, from time to time, evaluated and, in some cases, promulgated new rules and regulations regarding competitive lease bidding, venting and flaring, oil and gas measurement and royalty payment obligations for production from federal lands. In addition, President Biden and certain members of his administration have expressed support for, and have taken steps to implement, additional restrictions on oil and gas activities on federal lands, including orders temporarily limiting the approval of new leases and drilling permits to certain high-ranking officials within the Department of the Interior, as well as a pause on entering into future oil and gas leases on public lands.

We strive to conduct our operations in a socially and environmentally responsible manner, which includes compliance with applicable law. We are subject to many federal, state, and local laws and regulations concerning occupational safety and health as well as the discharge of materials into, and the protection of, the environment and natural resources. Environmental laws and regulations relate to:

Failure to comply with these laws and regulations can lead to the imposition of remedial liabilities, administrative, civil or criminal fines or penalties or injunctions limiting our operations in affected areas. Moreover, multiple environmental laws provide for citizen suits, which can allow environmental organizations to sue operators for alleged violations of environmental law. Environmental organizations also can assert legal and administrative challenges to certain actions of oil and gas regulators, such as the BLM, for allegedly failing to comply with environmental laws, which can result in delays in obtaining permits or other necessary authorizations. Environmental protection and health and safety compliance are necessary, manageable parts of our business. We have been able to plan for and comply with environmental, safety and health initiatives without materially altering our operating strategy or incurring significant unreimbursed expenditures. However, based on regulatory trends and increasingly stringent laws and permitting requirements, our capital expenditures and operating expenses related to the protection of the environment and safety and health compliance have increased over the years and may continue to increase.

Our business and operations, and our industry in general, are subject to a variety of risks. The risks described below may not be the only risks we face, as our business and operations may also be subject to risks that we do not yet know of, or that we currently

believe are immaterial. If any of the following risks should occur, our business, financial condition, results of operations and liquidity could be materially and adversely impacted. As a result, holders of our securities could lose part or all of their investment in Devon.

Our financial condition, results of operations and the value of our properties are highly dependent on the general supply and demand for oil, gas and NGLs, which impact the prices we ultimately realize on our sales of these commodities. Historically, market prices and our realized prices have been volatile. For example, over the last five years, monthly NYMEX WTI oil and NYMEX Henry Hub gas prices ranged from highs of over $67 per Bbl and $4.80 per MMBtu, respectively, to lows of under $30 per Bbl and $1.50 per MMBtu, respectively. Such volatility is likely to continue in the future due to numerous factors beyond our control, including, but not limited to:

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

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 significantly reduced global economic activity, resulting in an unprecedented decline in the demand for oil and other commodities during 2020. Combined with other factors, this decline in demand caused a swift and material deterioration in commodity prices in early 2020, which adversely impacted our results of operations for 2020 and contributed to our recognition of a material asset impairment to our oil and gas assets during the first quarter of 2020. 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 downturns, or protracted periods of depressed commodity prices, could have significant adverse consequences for our financial condition and liquidity. Moreover, any such downturns 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.

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. 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 disrupted or otherwise 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.

The COVID-19 pandemic and its related effects continue to 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 vaccination and other responsive actions to stop 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 a pandemic would adversely affect our business, financial condition and results of operations.

Estimates of Oil, Gas and NGL Reserves Are Uncertain and May Be Subject to Revision

The process of estimating oil, gas and NGL reserves is complex and requires significant judgment in the evaluation of available geological, engineering and economic data for each reservoir, particularly for new discoveries. Because of the high degree of judgment involved, different reserve engineers may develop different estimates of reserve quantities and related revenue based on the same data. In addition, the reserve estimates for a given reservoir may change substantially over time as a result of several factors, including additional development and appraisal activity, the viability of production under varying economic conditions, including commodity price declines, and variations in production levels and associated costs. Consequently, material revisions to existing reserves estimates may occur as a result of changes in any of these factors. Such revisions to proved reserves could have an adverse effect on our financial condition and the value of our properties, as well as the estimates of our future net revenue and profitability. Our policies and internal controls related to estimating and recording reserves are included in “Items 1 and 2. Business and Properties” of this report.

Discoveries or Acquisitions of Reserves Are Needed to Avoid a Material Decline in Reserves and Production

The production rates from oil and gas properties generally decline as reserves are depleted, while related per unit production costs generally increase due to decreasing reservoir pressures and other factors. Moreover, our current development activity is focused on unconventional oil and gas assets, which generally have significantly higher decline rates as compared to conventional assets. Therefore, our estimated proved reserves and future oil, gas and NGL production will decline materially as reserves are produced unless we conduct successful exploration and development activities, such as identifying additional producing zones in existing wells, utilizing secondary or tertiary recovery techniques or acquiring additional properties containing proved reserves. Consequently, our future oil, gas and NGL production and related per unit production costs are highly dependent upon our level of success in finding or acquiring additional reserves.

We Are Subject to Extensive Governmental Regulation, Which Can Change and Could Adversely Impact Our Business

Our operations are subject to extensive federal, state, local and other laws, rules and regulations, including with respect to environmental matters, worker health and safety, wildlife conservation, the gathering and transportation of oil, gas and NGLs, conservation policies, reporting obligations, royalty payments, unclaimed property and the imposition of taxes. Such regulations include requirements for permits to drill and to conduct other operations and for provision of financial assurances (such as bonds) covering drilling, completion and well operations and decommissioning obligations. If permits are not issued, or if unfavorable restrictions or conditions are imposed on our drilling or completion activities, we may not be able to conduct our operations as planned. In addition, we may be required to make large expenditures to comply with applicable governmental laws, rules, regulations, permits or orders. For example, certain regulations require the plugging and abandonment of wells and removal of production facilities by current and former operators, including corporate successors of former operators. These requirements may result in significant costs associated with the removal of tangible equipment and other restorative actions.

In addition, changes in public policy have affected, and in the future could further affect, our operations. For example, President Biden and certain members of his administration and Congress have expressed support for, and have taken steps to implement, efforts to transition the economy away from fossil fuels and to promote stricter environmental regulations, and such proposals could impose new and more onerous burdens on our industry and business. These and other regulatory and public policy developments could, among other things, restrict production levels, delay necessary permitting, impose price controls, change environmental protection requirements, impose restrictions on pipelines or other necessary infrastructure and increase taxes, royalties and other amounts payable to governments or governmental agencies. Our operating and other compliance costs could increase further if existing laws and regulations are revised or reinterpreted, or if new laws and regulations become applicable to our operations. In addition, changes in public policy may indirectly impact our operations by, among other things, increasing the cost of supplies and equipment and

fostering general economic uncertainty. Although we are unable to predict changes to existing laws and regulations, such changes could significantly impact our profitability, financial condition and liquidity, particularly changes related to leasing and permitting on federal lands, hydraulic fracturing, environmental matters more generally, seismic activity and income taxes, as discussed below.

Federal Lands – President Biden and certain members of his administration have expressed support for, and have taken steps to implement, additional regulation of oil and gas leasing and permitting on federal lands. Such proposals range from more onerous permitting requirements to an outright moratorium on new oil and gas leasing and permitting on federal lands. For example, on January 20, 2021, the Acting Secretary of the Department of the Interior issued an order temporarily limiting the authority to approve certain fossil fuel authorizations on federal lands, including the approval of new leases and new drilling permits, to certain high-ranking officials within the Department of the Interior. In addition, President Biden issued an executive order on January 27, 2021 directing the Secretary of the Interior to pause on entering new oil and gas leases on public lands to the extent possible and to launch a rigorous review of all existing leasing and permitting practices related to fossil fuel development on public lands. While it is not possible at this time to predict the ultimate impact of these or any other future regulatory changes, any additional restrictions or prohibitions on our ability to operate on federal lands could adversely impact our business in the Delaware and Powder River Basins, as well as other areas where we operate under federal leases. Post-merger, less than 20% of our total leasehold resides on federal lands primarily located in the Delaware and Powder River Basins.

Hydraulic Fracturing – In recent years, various federal agencies have asserted regulatory authority over certain aspects of the hydraulic fracturing process. For example, the EPA has issued regulations under the federal Clean Air Act establishing performance standards for oil and gas activities, including standards for the capture of air emissions released during hydraulic fracturing, and it finalized in 2016 regulations that prohibit the discharge of wastewater from hydraulic fracturing operations to publicly owned wastewater treatment plants. The EPA also released a report in 2016 finding that certain aspects of hydraulic fracturing, such as water withdrawals and wastewater management practices, could result in impacts to water resources in certain circumstances. The BLM previously finalized regulations to regulate hydraulic fracturing on federal lands but subsequently issued a repeal of those regulations in 2017. Moreover, several states in which we operate have adopted, or stated intentions to adopt, laws or regulations that mandate further restrictions on hydraulic fracturing, such as requiring disclosure of chemicals used in hydraulic fracturing, imposing more stringent permitting, disclosure and well-construction requirements on hydraulic fracturing operations and establishing standards for the capture of air emissions released during hydraulic fracturing. In addition to state laws, local land use restrictions, such as city ordinances, may restrict drilling in general or hydraulic fracturing in particular.

Beyond these regulatory efforts, various policy makers, regulatory agencies and political leaders at the federal, state and local levels have proposed implementing even further restrictions on hydraulic fracturing, including prohibiting the technology outright. Although it is not possible at this time to predict the outcome of these or other proposals, any new restrictions on hydraulic fracturing that may be imposed in areas in which we conduct business could potentially result in increased compliance costs, delays or cessation in development or other restrictions on our operations.

Environmental Laws Generally – In addition to regulatory efforts focused on hydraulic fracturing, we are subject to various other federal, state and local laws and regulations relating to discharge of materials into, and protection of, the environment. These laws and regulations may, among other things, impose liability on us for the cost of remediating pollution that results from our operations or prior operations on assets we have acquired. Environmental laws may impose strict, joint and several liability, and failure to comply with environmental laws and regulations can result in the imposition of administrative, civil or criminal fines and penalties, as well as injunctions limiting operations in affected areas. Any future environmental costs of fulfilling our commitments to the environment are uncertain and will be governed by several factors, including future changes to regulatory requirements. Any such changes could have a significant impact on our operations and profitability.

Seismic Activity – Earthquakes in northern and central Oklahoma, southeastern New Mexico, western Texas and elsewhere have prompted concerns about seismic activity and possible relationships with the oil and gas industry. Legislative and regulatory initiatives intended to address these concerns may result in additional levels of regulation or other requirements that could lead to operational delays, increase our operating and compliance costs or otherwise adversely affect our operations. In addition, we are currently defending against certain third-party lawsuits and could be subject to additional claims, seeking alleged property damages or other remedies as a result of alleged induced seismic activity in our areas of operation.

Changes to Tax Laws – We are subject to U.S. federal income tax as well as income or capital taxes in various state and foreign jurisdictions, and our operating cash flow is sensitive to the amount of income taxes we must pay. In the jurisdictions in which we operate or previously operated, income taxes are assessed on our earnings after consideration of all allowable deductions and credits. Changes in the types of earnings that are subject to income tax, the types of costs that are considered allowable deductions (such as

intangible drilling costs) and the timing of such deductions, or the rates assessed on our taxable earnings would all impact our income taxes and resulting operating cash flow.

Concerns About Climate Change and Related Regulatory, Social and Market Actions May Adversely Affect Our Business

Continuing and increasing political and social attention to the issue of climate change has resulted in legislative, regulatory and other initiatives, including international agreements, to reduce greenhouse gas emissions, such as carbon dioxide and methane. Policy makers and regulators at both the U.S. federal and state levels have already imposed, or stated intentions to impose, laws and regulations designed to quantify and limit the emission of greenhouse gases. For example, both the EPA and the BLM have issued regulations for the control of methane emissions, which also include leak detection and repair requirements, for the oil and gas industry; although the methane specific requirements of some of these regulations have been repealed, similar or more stringent emissions requirements may be imposed by the Biden Administration. In addition, several states where we operate, including Wyoming, New Mexico and Texas, have already imposed, or stated intentions to impose, laws or regulations designed to reduce methane emissions from oil and gas exploration and production activities. With respect to more comprehensive regulation, policy makers and political leaders have made, or expressed support for, a variety of proposals, such as the development of cap-and-trade or carbon tax programs. In addition, President Biden has highlighted addressing climate change as a priority of his administration, and he previously released an energy plan calling for a number of sweeping changes to address climate change, including, among other measures, a national mobilization effort to achieve net-zero emissions for the U.S. economy by 2050, through increased use of renewable power, stricter fuel-efficiency standards and support for zero-emission vehicles. President Biden issued a number of executive orders in January 2021 with the purpose of implementing certain of these changes, including the rejoining of the Paris Agreement, a call for the issuance of more stringent methane emissions regulations for oil and gas facilities and an order directing federal agencies to procure electric vehicles. Although the full impact of these orders is uncertain at this time, the adoption and implementation of these or other initiatives may result in the restriction or cancellation of oil and natural gas activities, greater costs of compliance or consumption (thereby reducing demand for our products) or an impairment in our ability to continue our operations in an economic manner.

In addition to regulatory risk, other market and social initiatives resulting from the changing perception of climate change present risks for our business. For example, in an effort to promote a lower-carbon economy, there are various public and private initiatives subsidizing the development and adoption of alternative energy sources and technologies, including by mandating the use of specific fuels or technologies. These initiatives may reduce the competitiveness of carbon-based fuels, such as oil and gas. Moreover, an increasing number of financial institutions, funds and other sources of capital have begun restricting or eliminating their investment in oil and natural gas activities due to their concern regarding climate change. Such restrictions in capital could decrease the value of our business and make it more difficult to fund our operations. Finally, governmental entities and other plaintiffs have brought, and may continue to bring, claims against us and other oil and gas companies for purported damages caused by the alleged effects of climate change. These and the other regulatory, social and market risks relating to climate change described above could result in unexpected costs, increase our operating expense and reduce the demand for our products, which in turn could lower the value of our reserves and have an adverse effect on our profitability, financial condition and liquidity.

Our operating activities are subject to numerous costs and risks, including the risk that we will not encounter commercially productive oil or gas reservoirs. Drilling for oil, gas and NGLs can be unprofitable, not only from dry holes, but from productive wells that do not return a profit because of insufficient revenue from production or high costs. Substantial costs are required to locate, acquire and develop oil and gas properties, and we are often uncertain as to the amount and timing of those costs. Our cost of drilling, completing, equipping and operating wells is often uncertain before drilling commences. Declines in commodity prices and overruns in budgeted expenditures are common risks that can make a particular project uneconomic or less economic than forecasted. While both exploratory and developmental drilling activities involve these risks, exploratory drilling involves greater risks of dry holes or failure to find commercial quantities of hydrocarbons. In addition, our oil and gas properties can become damaged, our operations may be curtailed, delayed or canceled and the costs of such operations may increase as a result of a variety of factors, including, but not limited to:

The occurrence of one or more of these factors could result in a partial or total loss of our investment in a particular property, as well as significant liabilities. Moreover, certain of these events could result in environmental pollution and impact to third parties, including persons living in proximity to our operations, our employees and employees of our contractors, leading to possible injuries, death or significant damage to property and natural resources. For example, we have from time to time experienced well-control events that have resulted in various remediation and clean-up costs and certain of the other impacts described above.

In addition, we rely on our employees, consultants and sub-contractors to conduct our operations in compliance with applicable laws and standards. Any violation of such laws or standards by these individuals, whether through negligence, harassment, discrimination or other misconduct, could result in significant liability for us and adversely affect our business. For example, negligent operations by employees could result in serious injury, death or property damage, and sexual harassment or racial and gender discrimination could result in legal claims and reputational harm.

Our Hedging Activities Limit Participation in Commodity Price Increases and Involve Other Risks

We enter into financial derivative instruments with respect to a portion of our production to manage our exposure to oil, gas and NGL price volatility. To the extent that we engage in price risk management activities to protect ourselves from commodity price declines, we will be prevented from fully realizing the benefits of commodity price increases above the prices established by our hedging contracts. In addition, our hedging arrangements may expose us to the risk of financial loss in certain circumstances, including instances in which the contract counterparties fail to perform under the contracts. Moreover, as a result of the Dodd-Frank Wall Street Reform and Consumer Protection Act and other legislation and regulation, hedging transactions and many of our contract counterparties have become subject to increased governmental oversight and regulations in recent years. Although we cannot predict the ultimate impact of these laws and the related rulemaking, some of which is ongoing, existing or future regulations may adversely affect the cost and availability of our hedging arrangements.

We enter into a variety of transactions that expose us to counterparty credit risk. For example, we have exposure to financial institutions and insurance companies through our hedging arrangements, our syndicated revolving credit facility and our insurance policies. Disruptions in the financial markets or otherwise may impact these counterparties and affect their ability to fulfill their existing obligations and their willingness to enter into future transactions with us.

In addition, we are exposed to the risk of financial loss from trade, joint interest billing and other receivables. We sell our oil, gas and NGLs to a variety of purchasers, and, as an operator, we pay expenses and bill our non-operating partners for their respective share of costs. We also frequently look to buyers of oil and gas properties from us or our predecessors to perform certain obligations associated with the disposed assets, including the removal of production facilities and plugging and abandonment of wells. Certain of these counterparties or their successors may experience insolvency, liquidity problems or other issues and may not be able to meet their obligations and liabilities (including contingent liabilities) owed to, and assumed from, us, particularly during a depressed or volatile commodity price environment. Any such default may result in us being forced to cover the costs of those obligations and liabilities, which could adversely impact our financial results and condition.

Our Debt May Limit Our Liquidity and Financial Flexibility, and Any Downgrade of Our Credit Rating Could Adversely Impact Us

As of December 31, 2020, we had total indebtedness of $4.3 billion. Our indebtedness and other financial commitments have important consequences to our business, including, but not limited to:

In addition, we receive credit ratings from rating agencies in the U.S. with respect to our debt. Factors that may impact our credit ratings include, among others, debt levels, planned asset sales and purchases, liquidity, forecasted production growth and commodity prices. We are currently required to provide letters of credit or other assurances under certain of our contractual arrangements. Any credit downgrades could adversely impact our ability to access financing and trade credit, require us to provide additional letters of credit or other assurances under contractual arrangements and increase our interest rate under any credit facility borrowing as well as the cost of any other future debt.

Our business has become increasingly dependent on digital technologies, and we anticipate expanding the use of these technologies in our operations, including through artificial intelligence, process automation and data analytics. Concurrent with the growing dependence on technology is greater sensitivity to cyber attack related activities, which have increasingly targeted our industry. Cyber attackers often attempt to gain unauthorized access to digital systems for purposes of misappropriating confidential and proprietary information, intellectual property or financial assets, corrupting data or causing operational disruptions as well as preventing users from accessing systems or information for the purpose of demanding payment in order for users to regain access. These attacks may be perpetrated by third parties or insiders. Techniques used in these attacks often range from highly sophisticated efforts to electronically circumvent network security to more traditional intelligence gathering and social engineering aimed at obtaining information necessary to gain access. Cyber attacks may also be performed in a manner that does not require gaining unauthorized access, such as by causing denial-of-service attacks. In addition, our vendors, midstream providers and other business partners may separately suffer disruptions or breaches from cyber attacks, which, in turn, could adversely impact our operations and compromise our information. Although we have not suffered material losses related to cyber attacks to date, if we were successfully attacked, we could incur substantial remediation and other costs or suffer other negative consequences, including litigation risks. Moreover, as the sophistication of cyber attacks continues to evolve, we may be required to expend significant additional resources to further enhance our digital security or to remediate vulnerabilities.

Certain of the properties in which we have an interest are operated by other companies and involve third-party working interest owners. We have limited influence and control over the operation or future development of such properties, including compliance with environmental, health and safety regulations or the amount and timing of required future capital expenditures. These limitations and our dependence on the operator and other working interest owners for these properties could result in unexpected future costs and delays, curtailments or cancellations of operations or future development, which could adversely affect our financial condition and results of operations.

We rely on midstream facilities and systems owned and operated by others to process our gas production and to transport our oil, gas and NGL production to downstream markets. All or a portion of our production in one or more regions may be interrupted or shut in from time to time due to losing access to plants, pipelines or gathering systems. Such access could be lost due to a number of factors, including, but not limited to, weather conditions and natural disasters, accidents, field labor issues or strikes. Additionally, the midstream operators may be subject to constraints that limit their ability to construct, maintain or repair midstream facilities needed to process and transport our production. Such interruptions or constraints could negatively impact our production and associated profitability.

As discussed above, our business is hazardous and is subject to all of the operating risks normally associated with the exploration, development and production of oil, gas and NGLs. To mitigate financial losses resulting from these operational hazards, we maintain comprehensive general liability insurance, as well as insurance coverage against certain losses resulting from physical damages, loss of well control, business interruption and pollution events that are considered sudden and accidental. We also maintain workers’ compensation and employer’s liability insurance. However, our insurance coverage does not provide 100% reimbursement of potential losses resulting from these operational hazards. Additionally, we have limited or no insurance coverage for a variety of other risks, including pollution events that are considered gradual, war and political risks and fines or penalties assessed by governmental authorities. The occurrence of a significant event against which we are not fully insured could have an adverse effect on our profitability, financial condition and liquidity.

Strong competition exists in all sectors of the oil and gas industry. We compete with major integrated and independent oil and gas companies for the acquisition of oil and gas leases and properties. We also compete for the equipment and personnel required to explore, develop and operate properties. Typically, during times of rising commodity prices, drilling and operating costs will also increase. During these periods, there is often a shortage of drilling rigs and other oilfield services, which could adversely affect our ability to execute our development plans on a timely basis and within budget. Competition is also prevalent in the marketing of oil, gas and NGLs. Certain of our competitors have financial and other resources substantially greater than ours and may have established superior strategic long-term positions and relationships, including with respect to midstream take-away capacity. As a consequence, we may be at a competitive disadvantage in bidding for assets or services and accessing capital and downstream markets. In addition, many of our larger competitors may have a competitive advantage when responding to factors that affect demand for oil and gas production, such as changing worldwide price and production levels, the cost and availability of alternative energy sources and the application of government regulations.

Our Business Could Be Adversely Impacted by Investors Attempting to Effect Change

Stockholder activism has been increasing in our industry, and investors may from time to time attempt to effect changes to our business or governance, whether by stockholder proposals, public campaigns, proxy solicitations or otherwise. Such actions could adversely impact our business by distracting our board of directors and employees from core business operations, requiring us to incur increased advisory fees and related costs, interfering with our ability to successfully execute on strategic transactions and plans and provoking perceived uncertainty about the future direction of our business. Such perceived uncertainty may, in turn, make it more difficult to retain employees and could result in significant fluctuation in the market price of our common stock.

Our business depends, in part, on making acquisitions that complement or expand our current business and successfully integrating any acquired assets or businesses. If we are unable to make attractive acquisitions, our future growth could be limited. Furthermore, even if we do make acquisitions, they may not result in an increase in our cash flow from operations or otherwise result in the benefits anticipated due to various risks, including, but not limited to:

In addition, from time to time, we may sell or otherwise dispose of certain of our properties or businesses as a result of an evaluation of our asset portfolio and to help enhance our liquidity. These transactions also have inherent risks, including possible delays in closing, the risk of lower-than-expected sales proceeds for the disposed assets or business and potential post-closing claims for indemnification. Moreover, volatility in commodity prices may result in fewer potential bidders, unsuccessful sales efforts and a higher risk that buyers may seek to terminate a transaction prior to closing.

The ultimate success of the Merger will depend on, among other things, our ability to combine the legacy Devon and WPX businesses in a manner that realizes anticipated synergies and benefits. If we are not able to successfully achieve these synergies, or the cost to achieve these synergies is greater than expected, then the anticipated benefits of the Merger may not be realized fully or at all or may take longer to realize than expected. It is possible that the integration process could result in the loss of key employees, the loss of customers, the disruption of our ongoing businesses, inconsistencies in standards, controls, procedures and policies, unexpected integration issues, higher than expected integration costs and an overall post‑completion integration process that takes longer than originally anticipated. Furthermore, our board of directors and management team consist of directors and employees from each of the legacy companies. The integration of these individuals could require the reconciliation of differing priorities and strategic philosophies, which may not be successful or take longer than anticipated.

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.

Item 5. Market for Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities

Our common stock is traded on the NYSE under the “DVN” ticker symbol. On February 3, 2021, there were 12,611 holders of record of our common stock. We began paying regular quarterly cash dividends in the second quarter of 1993. Following the closing of the Merger, Devon initiated a “fixed plus variable” dividend strategy. Under this strategy, Devon plans to pay, on a quarterly basis, a fixed dividend amount and, potentially, a variable dividend amount, if any, to its stockholders. The declaration and payment of any future dividend, whether fixed or variable, will remain at the full discretion of the Board of Directors and will depend on Devon’s financial results, cash requirements, future prospects, COVID-19 impacts and other factors deemed relevant by the Devon Board. In determining the amount of the quarterly fixed dividend, the Board expects to consider a number of factors, including Devon’s financial condition, the commodity price environment and a general target of paying out approximately 10% of operating cash flow through the fixed dividend. Any variable dividend amount will be determined on a quarterly basis and will equal up to 50% of “excess free cash flow,” which is a non-GAAP measure and is computed as operating cash flow (a GAAP measure) before balance sheet changes, less capital expenditures and the fixed dividend. A number of factors will be considered when determining if a variable dividend payment will be made. Devon expects that the most critical factors will consist of Devon’s financial condition, including its cash balances and leverage metrics, as well as the commodity price outlook. Additional information on our dividends can be found in Note 18 in “Item 8. Financial Statements and Supplementary Data” of this report.

The following graph compares the cumulative TSR over a five-year period on Devon’s common stock with the cumulative total returns of the S&P 500 Index and peer groups of companies to which we compare our performance. In 2020, this peer group was recalibrated to better align with Devon’s go-forward size and operations, in light of our strategic transformation in 2019, and due to consolidation within the industry. The new 2020 peer group includes Apache Corporation, Chesapeake Energy Corporation, Cimarex Energy Co., Continental Resources, Inc., EOG Resources, Inc., Marathon Oil Corporation, Occidental Petroleum Corporation, Ovintiv, Inc. and Pioneer Natural Resources. In 2019, the peer group included Apache Corporation, Chesapeake Energy Corporation, ConocoPhillips, Continental Resources, Inc., EOG Resources, Inc., Hess Corporation, Marathon Oil Corporation, Murphy Oil Corporation, Occidental Petroleum Corporation, Ovintiv, Inc. and Pioneer Natural Resources Company. Anadarko Petroleum Corporation, Concho Resources, Inc. and Noble Energy, Inc. were previously included in these peer groups, but have been excluded as a result of being acquired as part of the continuing consolidation in the industry. The graph was prepared assuming $100 was invested on December 31, 2015 in Devon’s common stock, the peer groups and the S&P 500 Index, and dividends have been reinvested subsequent to the initial investment.

The graph and related information should not be deemed “soliciting material” or to be “filed” with the SEC, nor should such information be incorporated by reference into any future filing under the Securities Act of 1933, as amended, or the Securities Exchange Act of 1934, as amended, except to the extent that we specifically incorporate such information by reference into such a filing. The graph and information are included for historical comparative purposes only and should not be considered indicative of future stock performance.

The following table provides information regarding purchases of our common stock that were made by us during the fourth quarter of 2020 (shares in thousands).

Period	Total Number of Shares Purchased ⁽¹⁾		Average Price Paid per Share		Total Number of Shares Purchased As Part of Publicly Announced Plans or Programs ⁽²⁾		Maximum Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs ⁽²⁾
October 1 - October 31		63	$	8.98		—	$	962
November 1 - November 30		17	$	14.41		—	$	962
December 1 - December 31		8	$	14.93		—	$	—
Total		88	$	10.58		—

Under the Devon Plan, eligible employees previously had the option to purchase shares of our common stock through an investment in the Devon Stock Fund, which is administered by an independent trustee. Eligible employees purchased approximately 14,000 shares of our common stock in 2020, at then-prevailing stock prices, that they held through their ownership in the Devon Stock Fund. We acquired the shares of our common stock sold under this plan through open-market purchases.

Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations

The following discussion and analysis presents management’s perspective of our business, financial condition and overall performance. This information is intended to provide investors with an understanding of our past performance, current financial condition and outlook for the future and should be read in conjunction with “Item 8. Financial Statements and Supplementary Data” of this report.

The following discussion and analyses generally focus on 2020 and 2019 items and year-to-year comparisons between 2020 and 2019. Discussions of 2018 items and year-to-year comparisons between 2019 and 2018 that are not included in this report can be found in “Management’s Discussion and Analysis of Financial Condition and Results or Operations” in Part II, Item 7 of our 2019 Annual Report on Form 10-K.

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 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 was exacerbated by uncertainty regarding the future global supply of oil due to disputes between Russia and the members of OPEC 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. By the end of 2020, NYMEX WTI oil prices recovered to approximately $50/Bbl, and we expect oil and other commodity prices to remain volatile for the foreseeable future.

Driven by the coronavirus pandemic, 2020 was a challenging year for the oil and gas industry and our business. Social distancing restrictions, government lockdowns and individual behavior changes all reduced transportation needs, which negatively impacted the demand for oil. The resulting drop in oil prices and cash generated from our operations necessitated a change in our plans. We aggressively reduced our planned capital investment 45%, selectively curtailed production and initiated sustainable cost-reduction measures. Despite these challenges, we continued to improve our capital efficiency and controllable costs per unit of production. Importantly, we maintained competitive leverage and debt metrics.

These market forces led to opportunities for select companies in our industry to create shareholder value from mergers and acquisitions. And, on September 26, 2020, we entered into the Merger Agreement, providing for an all-stock merger of equals with WPX which successfully closed on January 7, 2021. The Merger has created a leading oil producer in the U.S., with an asset base underpinned by premium acreage in the economic core of the Delaware Basin. This strategic combination accelerates our transition to a cash-return business model, including the implementation of a fixed plus variable dividend strategy.

As evidenced by our recent performance highlights below, we remain focused on building economic value by executing on our strategic priorities of disciplined oil volume growth while cutting operational and corporate costs, reducing reinvestment rates to maximize free cash flow, maintaining low leverage, delivering cash returns to our shareholders and pursuing ESG excellence. As we capture synergies and other benefits from the Merger, we expect to improve across all these performance measures.

Trends of our annual earnings, operating cash flow, EBITDAX and capital expenditures are shown below. The annual earnings chart presents amounts pertaining to both Devon’s continuing and discontinued operations. The annual 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 7.

Our net earnings in recent years have been significantly impacted by divestiture transactions, asset impairments and temporary, noncash adjustments to the value of our commodity hedges. Net earnings in 2018 included a $2.2 billion gain on our EnLink disposition, a $0.5 billion hedge valuation gain and a $0.2 billion gain on asset dispositions from continuing operations, all net of taxes. Net earnings in 2019 included a $0.4 billion hedge valuation loss, $0.2 billion net gains and charges related to our Canadian disposition and a $0.6 billion asset impairment related to our Barnett Shale disposition, all net of taxes. Net earnings in 2020 included $2.3 billion of asset impairments on our proved and unproved properties and a $0.1 billion hedge valuation loss, both net of taxes. Excluding these amounts, our core earnings have been more stable over recent years but continue to be heavily influenced by commodity prices.

Despite our portfolio enhancements, aggressive cost reductions and operational advancements, our 2020 financial results were challenged by commodity prices and deterioration of the macro-economic environment resulting from the unprecedented COVID-19 pandemic. Our earnings decreased from 2019 to 2020 due to a decline in overall commodity prices. Led by a 31% decline in WTI from 2019 to 2020, our unhedged combined realized price decreased 31%, while our hedged price decreased 26%. In response to this commodity price environment, we reduced our aggregate production and G&A expenses 13% compared to 2019.

Like earnings, our operating cash flow is sensitive to volatile commodity prices. EBITDAX, which excludes financial amounts related to discontinued operations, and operating cash flow continue to be impacted from the COVID-19 pandemic and declines in commodity prices. As operating cash flow has declined, we reduced our 2020 capital expenditures by approximately $800 million, or 45% compared to the original capital budget.

As of December 31, 2020, we had $5.2 billion of liquidity comprised of $2.2 billion of cash and $3.0 billion of available credit under our Senior Credit Facility. We had $4.3 billion of debt outstanding with no maturities until the end of 2025. Post-merger, approximately 50% and 55% of our 2021 oil and gas production is hedged, respectively. These contracts consist of a variety of trade types 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.

In 2020, Devon marked its 49th anniversary in the oil and gas business and its 32nd year as a public company. Due to our financial strength, our strong leadership team and our portfolio of quality assets, during 2020, we were able to successfully navigate through periods of commodity price volatility and economic uncertainty caused by the COVID-19 global pandemic. We also announced a transformational merger of equals with WPX that nearly doubles the size and scale of Devon’s oil production while further strengthening the quality of our portfolio of assets without deteriorating our balance sheet strength. The transaction was completed on January 7, 2021.

With the combination of the Devon and WPX leadership teams, and respective portfolios of quality assets, we expect to build on our successful track record of delivering value for our shareholders while remaining committed to safeguarding our long-term financial strength. With the transaction, Devon creates a leading position in the Delaware Basin while also adding the oily Williston Basin to our portfolio of assets. Looking forward, the strategic combination with WPX accelerates our planned cash return business model that includes targeted capital reinvestment rates of 70 to 80 percent of operating cash flow and a disciplined returns-driven strategy to generate higher free cash flow. Our strategy is underpinned by the maintenance of a disciplined oil growth target of up to 5 percent annually, while achieving margin growth through operational and corporate cost reductions. We expect to prioritize the deployment of our free cash flow toward maintaining a strong balance sheet through debt reduction and returning excess cash to shareholders through cash dividends using our innovative fixed plus variable dividend framework.

Our disciplined growth strategy is in response to current market fundamentals that indicate a slow recovery in global oil demand along with market prices for crude oil and natural gas that remain inherently volatile. In 2020, WTI oil prices averaged $39.59 per barrel versus $57.02 per barrel in 2019. Crude prices experienced tremendous volatility in 2020 with a geopolitical price war in March, followed by a steep decline in global oil demand related to the COVID-19 pandemic and associated lockdowns. Looking ahead, current market fundamentals indicate that 2021 crude pricing is expected to improve, supported by a slow recovery in demand with the easing of lockdown measures, the rollout of COVID-19 vaccines and declines in shale production. These factors indicate a balanced market by the second half of 2021. However, uncertainty still exists depending on actions taken by OPEC+ countries in supporting a balanced global crude supply. Natural gas and NGL prices also faced strong headwinds in early 2020 due to the COVID-19 pandemic as lockdowns negatively impacted demand. During the summer of 2020, U.S. gas prices were pressured by U.S. liquefied natural gas export cancellations from decreased global demand outlook. Looking forward, gas and NGL prices have improved due to declines in associated gas volumes, and strong recovery in global demand.

To mitigate our exposure to commodity market volatility and ensure our financial strength, we continue to execute a disciplined, risk-management hedging program. Our hedging program incorporates both systematic hedges added on a regular basis and discretionary hedges layered in on an opportunistic basis to take advantage of favorable market conditions. We are currently adding 2021 hedge positions at desirable prices where post-merger we currently have approximately 50% of our anticipated oil volumes and 55% of our anticipated gas volumes hedged. We are also actively adding attractive hedges for 2022. Further insulating our cash flow, we continue to examine and, when appropriate, execute attractive regional basis swap hedges to protect price realizations across our portfolio.

In connection with the Merger, we announced expected annual cost savings and margin improvements of $575 million, including legacy Devon cost reductions already underway and additional synergies expected through the integration of the WPX business with that of Devon. With our 2021 capital program, we expect to continue our capital-efficiency focus and our steadfast commitment to capital discipline. To achieve our 2021 capital program objectives that maximize free cash flow, over 70 percent of our 2021 spend will be focused on our highest margin U.S. oil play, the Delaware Basin. We expect to continue to leverage the strengths of our multi-basin strategy and deploy the remainder of our 2021 capital in our remaining core areas of the Eagle Ford, Anadarko Basin, Powder River Basin and Williston Basin. In total, our 2021 operating plan is expected to maintain our oil production at similar levels as 2020 on a pro forma combined basis.

The following graph, 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 35.

Our 2020 net loss from continuing operations was $2.5 billion, compared to a net loss from continuing operations of $79 million for 2019. The graph below shows the change in net loss from 2019 to 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

	2020		% of Total			2019		Change
Oil (MBbls/d)
Delaware Basin		85		55	%		70		+21	%
Powder River Basin		19		12	%		17		+11	%
Eagle Ford		24		15	%		23		+1	%
Anadarko Basin		20		13	%		31		- 35	%

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		6

Items 1 and 2. Business and Properties		6
Item 1A. Risk Factors		14
Item 1B. Unresolved Staff Comments		22
Item 3. Legal Proceedings		22
Item 4. Mine Safety Disclosures		22

PART II		23

Item 5. Market for Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities		23
Item 6. Selected Financial Data		25
Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations		26
Item 7A. Quantitative and Qualitative Disclosures about Market Risk		48
Item 8. Financial Statements and Supplementary Data		49
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure		104
Item 9A. Controls and Procedures		104
Item 9B. Other Information		104

PART III		106

Item 10. Directors, Executive Officers and Corporate Governance		106
Item 11. Executive Compensation		106
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters		106
Item 13. Certain Relationships and Related Transactions, and Director Independence		106
Item 14. Principal Accountant Fees and Services		106

PART IV		107

Item 15. Exhibits and Financial Statement Schedules		107
Item 16. Form 10-K Summary		116
Signatures		117


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


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

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

		As presented in the graph at the left, our operating achievements are subject to the volatility of commodity prices. Over the last four years, NYMEX WTI oil and NYMEX Henry Hub gas prices ranged from average highs of $64.79 per Bbl and $3.11 per MMBtu, respectively, to average lows of $39.59 per Bbl and $2.08 per MMBtu, respectively.