dvn-10q_20170630.htm

Table of Contents

 

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

Form 10-Q

 

(Mark One)

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

For the quarterly period ended June 30, 2017

or

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

Commission File Number 001-32318

 

DEVON ENERGY CORPORATION

(Exact name of registrant as specified in its charter)

 

Delaware

 

73-1567067

(State or other jurisdiction of

incorporation or organization)

 

(I.R.S. Employer

identification No.)

 

 

333 West Sheridan Avenue, Oklahoma City, Oklahoma

 

73102-5015

(Address of principal executive offices)

 

(Zip code)

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

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

 

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 and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted 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 and post such files).    Yes      No  

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

 

Large accelerated filer

 

Accelerated filer

 

Non-accelerated filer

 

Smaller reporting company

 

Emerging growth company

 

 

 

 

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.  

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

On July 19, 2017, 525.6 million shares of common stock were outstanding.

 

 


Table of Contents

DEVON ENERGY CORPORATION

FORM 10-Q

TABLE OF CONTENTS

 

Part I. Financial Information

 

Item 1.

 

Financial Statements

6

 

 

Consolidated Comprehensive Statements of Earnings

6

 

 

Consolidated Statements of Cash Flows

7

 

 

Consolidated Balance Sheets

8

 

 

Consolidated Statements of Stockholders’ Equity

9

 

 

Notes to Consolidated Financial Statements

10

Item 2.

 

Management’s Discussion and Analysis of Financial Condition and Results of Operations

28

Item 3.

 

Quantitative and Qualitative Disclosures About Market Risk

42

Item 4.

 

Controls and Procedures

42

 

 

 

 

Part II. Other Information

 

Item 1.

 

Legal Proceedings

43

Item 1A.

 

Risk Factors

43

Item 2.

 

Unregistered Sales of Equity Securities and Use of Proceeds

43

Item 3.

 

Defaults Upon Senior Securities

43

Item 4.

 

Mine Safety Disclosures

43

Item 5.

 

Other Information

43

Item 6.

 

Exhibits

44

 

 

 

 

Signatures

 

 

45

 

 

 

2

 


Table of Contents

DEFINITIONS

Unless the context otherwise indicates, references to “us,” “we,” “our,” “ours,” “Devon” and the “Company” refer to Devon Energy Corporation and its consolidated subsidiaries. In addition, the following are other abbreviations and definitions of certain terms used within this Quarterly Report on Form 10-Q:

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

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

“ASU” means Accounting Standards Update.

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

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

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

“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.

“Canadian Plan” means Devon Canada Corporation Incentive Savings Plan.

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

“Devon Plan” means Devon Energy Corporation Incentive Savings Plan.

“E&P” means exploration and production activities.

“EnLink” means EnLink Midstream Partners, LP, a master limited partnership.

“FASB” means Financial Accounting Standards Board.

“G&A” means general and administrative expenses.

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

“General Partner” means EnLink Midstream, LLC, the indirect general partner of EnLink.

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

“LIBOR” means London Interbank Offered Rate.

“LOE” means lease operating expenses.

“MBbls” means thousand barrels.

“MBoe” means thousand Boe.

“Mcf” means thousand cubic feet.

“MMBoe” means million Boe.

3

 


Table of Contents

“MMBtu” means million Btu.

“MMcf” means million cubic feet.

“N/M” means not meaningful.

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

“NYMEX” means New York Mercantile Exchange.

“OPIS” means Oil Price Information Service.

“SEC” means United States Securities and Exchange Commission.

“Senior Credit Facility” means Devon’s syndicated unsecured revolving line of credit.

“TSR” means total shareholder return.

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

“WTI” means West Texas Intermediate.

“/d” means per day.

“/Bbl” means per barrel.

“/MMBtu” means per MMBtu.

4

 


Table of Contents

INFORMATION REGARDING FORWARD-LOOKING STATEMENTS

This report includes “forward-looking statements” as defined by the SEC. Such statements include those concerning strategic plans, our expectations and objectives for future operations, as well as other future events or conditions, and are often identified by use of the words “expects,” “believes,” “will,” “would,” “could,” “forecasts,” “projections,” “estimates,” “plans,” “expectations,” “targets,” “opportunities,” “potential,” “anticipates,” “outlook” and other similar terminology. Such forward-looking statements are based on our examination of historical operating trends, the information used to prepare our December 31, 2016 reserve reports and other data in our possession or available from third parties. Such statements are subject to a number of assumptions, risks and uncertainties, many of which are beyond our control. Consequently, actual future results could differ materially from our expectations due to a number of factors, including, but not limited to:

 

the volatility of oil, gas and NGL prices;

 

uncertainties inherent in estimating oil, gas and NGL reserves;

 

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

 

the uncertainties, costs and risks involved in exploration and development activities;

 

risks related to our hedging activities;

 

counterparty credit risks;

 

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

 

risks relating to our indebtedness;

 

our ability to successfully complete mergers, acquisitions and divestitures;

 

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

 

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

 

midstream capacity constraints and potential interruptions in production;

 

competition for leases, materials, people and capital;

 

cyberattacks targeting our systems and infrastructure; and

 

any of the other risks and uncertainties discussed in this report, our 2016 Annual Report on Form 10-K and our other filings 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 assume no duty to update or revise our forward-looking statements based on new information, future events or otherwise.

 

 

5

 


Table of Contents

Part I.  Financial Information

Item 1.  Financial Statements

DEVON ENERGY CORPORATION AND SUBSIDIARIES

CONSOLIDATED COMPREHENSIVE STATEMENTS OF EARNINGS

 

 

 

 

 

 

 

 

 

 

Three Months Ended June 30,

 

 

Six Months Ended June 30,

 

 

 

2017

 

 

2016

 

 

2017

 

 

2016

 

 

 

(Unaudited)

 

 

 

(Millions, except per share amounts)

 

Oil, gas and NGL sales

 

$

1,206

 

 

$

1,085

 

 

$

2,515

 

 

$

1,910

 

Oil, gas and NGL derivatives

 

 

126

 

 

 

(142

)

 

 

358

 

 

 

(109

)

Marketing and midstream revenues

 

 

1,927

 

 

 

1,545

 

 

 

3,937

 

 

 

2,813

 

Asset dispositions and other

 

 

14

 

 

 

 

 

 

10

 

 

 

 

Total revenues and other

 

 

3,273

 

 

 

2,488

 

 

 

6,820

 

 

 

4,614

 

Lease operating expenses

 

 

399

 

 

 

416

 

 

 

785

 

 

 

860

 

Marketing and midstream operating expenses

 

 

1,703

 

 

 

1,338

 

 

 

3,506

 

 

 

2,404

 

General and administrative expenses

 

 

164

 

 

 

147

 

 

 

345

 

 

 

341

 

Production and property taxes

 

 

71

 

 

 

75

 

 

 

156

 

 

 

153

 

Depreciation, depletion and amortization

 

 

381

 

 

 

484

 

 

 

762

 

 

 

1,026

 

Asset impairments

 

 

 

 

 

1,497

 

 

 

7

 

 

 

4,532

 

Restructuring and transaction costs

 

 

 

 

 

24

 

 

 

 

 

 

271

 

Other operating items

 

 

13

 

 

 

4

 

 

 

11

 

 

 

24

 

Total operating expenses

 

 

2,731

 

 

 

3,985

 

 

 

5,572

 

 

 

9,611

 

Operating income (loss)

 

 

542

 

 

 

(1,497

)

 

 

1,248

 

 

 

(4,997

)

Net financing costs

 

 

116

 

 

 

163

 

 

 

243

 

 

 

327

 

Other nonoperating items

 

 

(32

)

 

 

85

 

 

 

(51

)

 

 

106

 

Earnings (loss) before income taxes

 

 

458

 

 

 

(1,745

)

 

 

1,056

 

 

 

(5,430

)

Income tax expense (benefit)

 

 

7

 

 

 

(182

)

 

 

26

 

 

 

(399

)

Net earnings (loss)

 

 

451

 

 

 

(1,563

)

 

 

1,030

 

 

 

(5,031

)

Net earnings (loss) attributable to noncontrolling interests

 

 

26

 

 

 

7

 

 

 

40

 

 

 

(405

)

Net earnings (loss) attributable to Devon

 

$

425

 

 

$

(1,570

)

 

$

990

 

 

$

(4,626

)

Net earnings (loss) per share attributable to Devon:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Basic

 

$

0.81

 

 

$

(3.04

)

 

$

1.88

 

 

$

(9.33

)

Diluted

 

$

0.80

 

 

$

(3.04

)

 

$

1.87

 

 

$

(9.33

)

Comprehensive earnings (loss):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net earnings (loss)

 

$

451

 

 

$

(1,563

)

 

$

1,030

 

 

$

(5,031

)

Other comprehensive earnings, net of tax:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Foreign currency translation

 

 

2

 

 

 

3

 

 

 

 

 

 

26

 

Pension and postretirement plans

 

 

4

 

 

 

5

 

 

 

9

 

 

 

9

 

Other

 

 

(2

)

 

 

 

 

 

(2

)

 

 

 

Other comprehensive earnings, net of tax

 

 

4

 

 

 

8

 

 

 

7

 

 

 

35

 

Comprehensive earnings (loss)

 

 

455

 

 

 

(1,555

)

 

 

1,037

 

 

 

(4,996

)

Comprehensive earnings (loss) attributable to

   noncontrolling interests

 

 

26

 

 

 

7

 

 

 

40

 

 

 

(405

)

Comprehensive earnings (loss) attributable to Devon

 

$

429

 

 

$

(1,562

)

 

$

997

 

 

$

(4,591

)

 

See accompanying notes to consolidated financial statements

 

6

 


Table of Contents

DEVON ENERGY CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

 

 

 

 

 

 

 

 

 

Three Months Ended June 30,

 

 

Six Months Ended June 30,

 

 

 

2017

 

 

2016

 

 

2017

 

 

2016

 

 

 

(Unaudited)

 

 

 

(Millions)

 

Cash flows from operating activities:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net earnings (loss)

 

$

451

 

 

$

(1,563

)

 

$

1,030

 

 

$

(5,031

)

Adjustments to reconcile net earnings (loss) to net cash

   from operating activities:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Depreciation, depletion and amortization

 

 

381

 

 

 

484

 

 

 

762

 

 

 

1,026

 

Asset impairments

 

 

 

 

 

1,497

 

 

 

7

 

 

 

4,532

 

Gains on asset sales

 

 

(11

)

 

 

 

 

 

(7

)

 

 

 

Deferred income tax benefit

 

 

(5

)

 

 

(179

)

 

 

(6

)

 

 

(386

)

Commodity derivatives

 

 

(126

)

 

 

142

 

 

 

(358

)

 

 

109

 

Cash settlements on commodity derivatives

 

 

11

 

 

 

(16

)

 

 

19

 

 

 

3

 

Other derivatives and financial instruments

 

 

16

 

 

 

81

 

 

 

7

 

 

 

308

 

Cash settlements on other derivatives and

   financial instruments

 

 

2

 

 

 

(28

)

 

 

 

 

 

(151

)

Asset retirement obligation accretion

 

 

14

 

 

 

20

 

 

 

31

 

 

 

39

 

Share-based compensation

 

 

43

 

 

 

32

 

 

 

89

 

 

 

140

 

Other

 

 

(49

)

 

 

36

 

 

 

(49

)

 

 

(158

)

Net change in working capital

 

 

72

 

 

 

(143

)

 

 

87

 

 

 

71

 

Change in long-term other assets

 

 

9

 

 

 

(40

)

 

 

10

 

 

 

13

 

Change in long-term other liabilities

 

 

2

 

 

 

22

 

 

 

22

 

 

 

(5

)

Net cash from operating activities

 

 

810

 

 

 

345

 

 

 

1,644

 

 

 

510

 

Cash flows from investing activities:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Capital expenditures

 

 

(721

)

 

 

(489

)

 

 

(1,468

)

 

 

(1,238

)

Acquisitions of property, equipment and businesses

 

 

(13

)

 

 

(11

)

 

 

(33

)

 

 

(1,638

)

Proceeds from sale of investment

 

 

 

 

 

 

 

 

190

 

 

 

 

Divestitures of property and equipment

 

 

76

 

 

 

191

 

 

 

114

 

 

 

209

 

Other

 

 

(1

)

 

 

(26

)

 

 

(4

)

 

 

(27

)

Net cash from investing activities

 

 

(659

)

 

 

(335

)

 

 

(1,201

)

 

 

(2,694

)

Cash flows from financing activities:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Borrowings of long-term debt, net of issuance costs

 

 

982

 

 

 

450

 

 

 

1,795

 

 

 

846

 

Repayments of long-term debt

 

 

(798

)

 

 

(290

)

 

 

(1,385

)

 

 

(549

)

Payment of installment payable

 

 

 

 

 

 

 

 

(250

)

 

 

 

Net short-term debt repayments

 

 

 

 

 

 

 

 

 

 

 

(626

)

Issuance of common stock

 

 

 

 

 

 

 

 

 

 

 

1,469

 

Issuance of subsidiary units

 

 

17

 

 

 

49

 

 

 

72

 

 

 

776

 

Dividends paid on common stock

 

 

(33

)

 

 

(33

)

 

 

(65

)

 

 

(158

)

Contributions from noncontrolling interests

 

 

8

 

 

 

3

 

 

 

29

 

 

 

6

 

Distributions to noncontrolling interests

 

 

(82

)

 

 

(74

)

 

 

(163

)

 

 

(147

)

Shares traded for tax withholdings

 

 

(3

)

 

 

(10

)

 

 

(64

)

 

 

(28

)

Other

 

 

 

 

 

(5

)

 

 

(2

)

 

 

(6

)

Net cash from financing activities

 

 

91

 

 

 

90

 

 

 

(33

)

 

 

1,583

 

Effect of exchange rate changes on cash

 

 

8

 

 

 

(12

)

 

 

 

 

 

14

 

Net change in cash and cash equivalents

 

 

250

 

 

 

88

 

 

 

410

 

 

 

(587

)

Cash and cash equivalents at beginning of period

 

 

2,119

 

 

 

1,635

 

 

 

1,959

 

 

 

2,310

 

Cash and cash equivalents at end of period

 

$

2,369

 

 

$

1,723

 

 

$

2,369

 

 

$

1,723

 

 

See accompanying notes to consolidated financial statements

7

 


Table of Contents

DEVON ENERGY CORPORATION AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

 

 

 

June 30, 2017

 

 

December 31, 2016

 

 

 

(Unaudited)

 

 

 

 

 

 

 

(Millions, except share data)

 

ASSETS

 

 

 

 

 

 

 

 

Current assets:

 

 

 

 

 

 

 

 

Cash and cash equivalents

 

$

2,369

 

 

$

1,959

 

Accounts receivable

 

 

1,248

 

 

 

1,356

 

Assets held for sale

 

 

 

 

 

193

 

Other current assets

 

 

469

 

 

 

264

 

Total current assets

 

 

4,086

 

 

 

3,772

 

Property and equipment, at cost:

 

 

 

 

 

 

 

 

Oil and gas, based on full cost accounting:

 

 

 

 

 

 

 

 

Subject to amortization

 

 

77,326

 

 

 

75,648

 

Not subject to amortization

 

 

3,048

 

 

 

3,437

 

Total oil and gas

 

 

80,374

 

 

 

79,085

 

Midstream and other

 

 

10,908

 

 

 

10,455

 

Total property and equipment, at cost

 

 

91,282

 

 

 

89,540

 

Less accumulated depreciation, depletion and amortization

 

 

(74,460

)

 

 

(73,350

)

Property and equipment, net

 

 

16,822

 

 

 

16,190

 

Goodwill

 

 

3,964

 

 

 

3,964

 

Other long-term assets

 

 

1,942

 

 

 

1,987

 

Total assets

 

$

26,814

 

 

$

25,913

 

LIABILITIES AND STOCKHOLDERS’ EQUITY

 

 

 

 

 

 

 

 

Current liabilities:

 

 

 

 

 

 

 

 

Accounts payable

 

$

692

 

 

$

642

 

Revenues and royalties payable

 

 

949

 

 

 

908

 

Other current liabilities

 

 

891

 

 

 

1,066

 

Total current liabilities

 

 

2,532

 

 

 

2,616

 

Long-term debt

 

 

10,558

 

 

 

10,154

 

Asset retirement obligations

 

 

1,078

 

 

 

1,226

 

Other long-term liabilities

 

 

657

 

 

 

894

 

Deferred income taxes

 

 

659

 

 

 

648

 

Stockholders’ equity:

 

 

 

 

 

 

 

 

Common stock, $0.10 par value. Authorized 1.0 billion shares; issued 526 million and

   523 million shares in 2017 and 2016, respectively

 

 

53

 

 

 

52

 

Additional paid-in capital

 

 

7,211

 

 

 

7,237

 

Accumulated deficit

 

 

(656

)

 

 

(1,646

)

Accumulated other comprehensive earnings

 

 

291

 

 

 

284

 

Total stockholders’ equity attributable to Devon

 

 

6,899

 

 

 

5,927

 

Noncontrolling interests

 

 

4,431

 

 

 

4,448

 

Total stockholders’ equity

 

 

11,330

 

 

 

10,375

 

Total liabilities and stockholders’ equity

 

$

26,814

 

 

$

25,913

 

 

See accompanying notes to consolidated financial statements

 

 

8

 


Table of Contents

DEVON ENERGY CORPORATION AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Accumulated

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Additional

 

 

Retained

 

 

Other

 

 

 

 

 

 

 

 

 

 

Total

 

 

 

Common Stock

 

 

Paid-In

 

 

Earnings

 

 

Comprehensive

 

 

Treasury

 

 

Noncontrolling

 

 

Stockholders’

 

 

 

Shares

 

 

Amount

 

 

Capital

 

 

(Accumulated Deficit)

 

 

Earnings

 

 

Stock

 

 

Interests

 

 

Equity

 

 

 

(Unaudited)

 

 

 

(Millions)

 

Six Months Ended June 30, 2017

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Balance as of December 31, 2016

 

 

523

 

 

$

52

 

 

$

7,237

 

 

$

(1,646

)

 

$

284

 

 

$

 

 

$

4,448

 

 

$

10,375

 

Net earnings

 

 

 

 

 

 

 

 

 

 

 

990

 

 

 

 

 

 

 

 

 

40

 

 

 

1,030

 

Other comprehensive earnings, net of tax

 

 

 

 

 

 

 

 

 

 

 

 

 

 

7

 

 

 

 

 

 

 

 

 

7

 

Restricted stock grants, net of cancellations

 

 

2

 

 

 

1

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

1

 

Common stock repurchased

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(41

)

 

 

 

 

 

(41

)

Common stock retired

 

 

 

 

 

 

 

 

(41

)

 

 

 

 

 

 

 

 

41

 

 

 

 

 

 

 

Common stock dividends

 

 

 

 

 

 

 

 

(65

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(65

)

Share-based compensation

 

 

1

 

 

 

 

 

 

69

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

69

 

Subsidiary equity transactions

 

 

 

 

 

 

 

 

11

 

 

 

 

 

 

 

 

 

 

 

 

106

 

 

 

117

 

Distributions to noncontrolling interests

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(163

)

 

 

(163

)

Balance as of June 30, 2017

 

 

526

 

 

$

53

 

 

$

7,211

 

 

$

(656

)

 

$

291

 

 

$

 

 

$

4,431

 

 

$

11,330

 

Six Months Ended June 30, 2016

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Balance as of December 31, 2015

 

 

418

 

 

$

42

 

 

$

4,996

 

 

$

1,781

 

 

$

230

 

 

$

 

 

$

3,940

 

 

$

10,989

 

Net loss

 

 

 

 

 

 

 

 

 

 

 

(4,626

)

 

 

 

 

 

 

 

 

(405

)

 

 

(5,031

)

Other comprehensive earnings, net of tax

 

 

 

 

 

 

 

 

 

 

 

 

 

 

35

 

 

 

 

 

 

 

 

 

35

 

Restricted stock grants, net of cancellations

 

 

3

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Common stock repurchased

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(21

)

 

 

 

 

 

(21

)

Common stock retired

 

 

 

 

 

 

 

 

(21

)

 

 

 

 

 

 

 

 

21

 

 

 

 

 

 

 

Common stock dividends

 

 

 

 

 

 

 

 

(33

)

 

 

(125

)

 

 

 

 

 

 

 

 

 

 

 

(158

)

Common stock issued

 

 

103

 

 

 

10

 

 

 

2,117

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

2,127

 

Share-based compensation

 

 

 

 

 

 

 

 

123

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

123

 

Subsidiary equity transactions

 

 

 

 

 

 

 

 

318

 

 

 

 

 

 

 

 

 

 

 

 

684

 

 

 

1,002

 

Distributions to noncontrolling interests

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(147

)

 

 

(147

)

Balance as of June 30, 2016

 

 

524

 

 

$

52

 

 

$

7,500

 

 

$

(2,970

)

 

$

265

 

 

$

 

 

$

4,072

 

 

$

8,919

 

 

 

See accompanying notes to consolidated financial statements

9

 


Table of Contents

DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

 

 

 

1.Summary of Significant Accounting Policies

The accompanying unaudited interim financial statements and notes of Devon have been prepared pursuant to the rules and regulations of the SEC. Pursuant to such rules and regulations, certain disclosures normally included in financial statements prepared in accordance with U.S. GAAP have been omitted. The accompanying unaudited interim financial statements and notes should be read in conjunction with the financial statements and notes included in Devon’s 2016 Annual Report on Form 10-K.

The accompanying unaudited interim financial statements furnished in this report reflect all adjustments that are, in the opinion of management, necessary for a fair statement of Devon’s results of operations and cash flows for the three-month and six-month periods ended June 30, 2017 and 2016 and Devon’s financial position as of June 30, 2017.

Recently Adopted Accounting Standards

In January 2017, Devon adopted ASU 2016-09, Compensation – Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting. Its objective is to simplify several aspects of the accounting for share-based payments, including income taxes when awards vest or are settled, statutory withholding and forfeitures. As the result of adoption, Devon made certain income tax presentation changes, most notably prospectively presenting excess tax benefits and deficiencies in the consolidated comprehensive statements of earnings and as operating cash flows in the consolidated statements of cash flows. Devon also retrospectively applied the new cash flow statement guidance dictating the presentation of shares traded for tax-withholding purposes as a financing activity. The adoption of the new guidance did not materially impact the consolidated financial statements for the six months ended June 30, 2017 or previously reported financial information but could have a more material future impact.

In January 2017, the FASB issued ASU 2017-04, Intangibles - Goodwill And Other (Topic 350)Simplifying the Test for Goodwill Impairment ("ASU 2017-04"). ASU 2017-04 simplifies the accounting for goodwill impairments by eliminating the requirement to compare the implied fair value of goodwill with its carrying amount as part of step two of the goodwill impairment test. Under ASU 2017-04, an entity should perform its goodwill impairment test by comparing the fair value of a reporting unit with its carrying amount. An impairment charge should be recognized for the amount by which the carrying amount exceeds the reporting unit's fair value. However, the impairment loss recognized should not exceed the total amount of goodwill allocated to that reporting unit. ASU 2017-04 is effective for annual reporting periods beginning after December 15, 2019, including any interim impairment tests within those annual periods, with early application for interim or annual goodwill impairment tests performed on testing dates after January 1, 2017. In January 2017, Devon elected to early adopt ASU 2017-04, and the adoption had no impact on the consolidated financial statements. Devon will perform future goodwill impairment tests according to ASU 2017-04.

Issued Accounting Standards Not Yet Adopted

The FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606). This ASU will supersede the revenue recognition requirements in Topic 605, Revenue Recognition and industry-specific guidance in Subtopic 932-605, Extractive Activities – Oil and Gas – Revenue Recognition. This ASU provides guidance concerning the recognition and measurement of revenue from contracts with customers. Its objective is to increase the usefulness of information in the financial statements regarding the nature, timing and uncertainty of revenues. The effective date for ASU 2014-09 was delayed through the issuance of ASU 2015-14, Revenue from Contracts with Customers – Deferral of the Effective Date, to annual and interim periods beginning in 2018, with early adoption permitted in 2017. Devon does not plan on early adopting this ASU. The ASU is required to be adopted using either the retrospective transition method, which requires restating previously reported results or the cumulative effect (modified retrospective) transition method, which utilizes a cumulative-effect adjustment to retained earnings in the period of adoption to account for prior period effects rather than restating previously reported results. Devon intends to use the cumulative effect transition method and does not anticipate this ASU will have a material impact on its balance sheet or related consolidated statement of earnings, stockholders’ equity or cash flows. Devon does not expect its annual disclosures will materially change upon adopting this ASU. However, Devon’s quarterly disclosures will materially expand upon adoption of this ASU. Devon is implementing a process to gather and provide the quarterly disclosures required by the ASU.

10

 


Table of Contents

DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

 

The FASB issued ASU 2016-02, Leases (Topic 842). This ASU will supersede the lease requirements in Topic 840, Leases. Its objective is to increase transparency and comparability among organizations. This ASU provides guidance requiring lessees to recognize most leases on their balance sheet. Lessor accounting does not significantly change, except for some changes made to align with new revenue recognition requirements. This ASU is effective for Devon beginning January 1, 2019 and will be applied using a modified retrospective transition method, which requires applying the new guidance to leases that exist or are entered into after the beginning of the earliest period in the financial statements. Early adoption is permitted, but Devon does not plan to early adopt. Devon has begun the process of evaluating contracts and gathering the necessary terms and data elements for purposes of determining the impact this ASU will have on its consolidated financial statements and related disclosures. Based on continuing research, Devon estimates at least 11,500 contracts and a large number of data elements must be gathered and reviewed to ensure proper accounting of these contracts once this ASU is effective. Recently, several companies, including certain upstream oil and gas companies, met with the FASB to discuss whether contracts for easements and rights-of-way are subject to the scope of ASU 2016-02 or other existing accounting standards. For Devon, these contracts represent a relatively small percentage of the aggregate value of contracts being evaluated but represent approximately 80% of the number of contracts. Therefore, this scoping decision could have a significant impact on the amount of effort required for Devon to adopt this ASU. Regardless, Devon anticipates the adoption of this standard will significantly impact its systems, processes and controls and is evaluating technology requirements and solutions needed to comply with the requirements of this ASU.

The FASB issued ASU No. 2017-07, Compensation – Retirement Benefits (Topic 715), Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost. This ASU will require entities to present the service cost component of net periodic benefit cost in the same line item as other employee compensation costs and present the other components of net periodic benefit cost outside of operating income in the income statement. Only the service cost component of net periodic benefit cost is eligible for capitalization. This ASU is effective for Devon beginning January 1, 2018, and income statement presentation changes will be applied retrospectively, while service cost component capitalization will be applied prospectively. Upon adoption of this ASU, Devon will reclassify $7 million, $14 million and $16 million of non-service cost components of net periodic benefit costs for 2017, 2016 and 2015, respectively, as other nonoperating items. Such amounts are currently classified in Devon’s G&A. No other changes upon adopting this ASU are expected to be material.  

 

2.

Acquisitions and Divestitures

Devon Acquisitions

On January 7, 2016, Devon acquired approximately 80,000 net acres (unaudited) and assets in the STACK play for approximately $1.5 billion. Devon funded the acquisition with $849 million of cash, after adjustments, and $659 million of common equity shares. The purchase price allocation was approximately $1.3 billion to unproved properties and approximately $200 million to proved properties.

 

Devon Asset Divestitures

In May 2017, Devon announced a program to divest approximately $1 billion of upstream assets. The non-core assets identified for monetization include select portions of the Barnett Shale focused primarily in and around Johnson County and other properties located principally within Devon’s U.S. resource base. Devon expects the divestiture process will take 12 to 18 months to complete. Devon plans to deploy divestiture proceeds toward its U.S. resource plays and to further strengthen its investment-grade financial position. The non-core divestiture plan is also expected to accelerate Devon’s transition to higher-margin production.

Subsequent to June 30, 2017, Devon reached an agreement to sell its non-core Eagle Ford assets in Lavaca County for $205 million, subject to certain adjustments. The transaction is expected to close in the second half of 2017. No gain or loss is expected to be recognized under the full cost method of accounting.

In June 2016, Devon divested its non-core Mississippian assets for approximately $200 million. Estimated proved reserves associated with these assets were approximately 11 MMBoe, or less than 1% of total U.S. proved reserves. Under full cost accounting rules, sales or dispositions of oil and gas properties are generally accounted for as adjustments to capitalized costs, with no recognition of a gain or loss. No gain or loss was recognized on the sale of the Mississippian assets.

11

 


Table of Contents

DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

 

EnLink Acquisitions

On January 7, 2016, EnLink acquired Anadarko Basin gathering and processing midstream assets, along with dedicated acreage service rights and service contracts, for approximately $1.4 billion. The purchase price allocation was $1.0 billion to intangible assets and approximately $400 million to property and equipment. EnLink funded the acquisition with approximately $215 million of General Partner common units and approximately $800 million of cash, primarily funded with the issuance of EnLink preferred units. The remaining $500 million of the purchase price was to be paid within one year with the option to defer $250 million of the final payment 24 months from the close date. The first installment payment of $250 million was paid in January 2017. The remaining $250 million payment is reported in other current liabilities in the accompanying consolidated balance sheets. The accretion of the discount is reported within net financing costs in the accompanying consolidated comprehensive statement of earnings.

EnLink Asset Divestitures

During the first quarter of 2017, EnLink divested its ownership interest in Howard Energy Partners for approximately $190 million.

 

3.

Derivative Financial Instruments

Objectives and Strategies

Devon periodically enters into derivative financial instruments with respect to a portion of its oil, gas and NGL production to hedge future prices received. Additionally, Devon and EnLink periodically enter into derivative financial instruments with respect to a portion of their oil, gas and NGL marketing activities. These commodity derivative financial instruments include financial price swaps, basis swaps and costless price collars. Devon periodically enters into interest rate swaps to manage its exposure to interest rate volatility and foreign exchange forward contracts to manage its exposure to fluctuations in the U.S. and Canadian dollar exchange rates. As of June 30, 2017, Devon did not have any open foreign exchange contracts.

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

Counterparty Credit Risk

By using derivative financial instruments, Devon is exposed to credit risk. Credit risk is the failure of the counterparty to perform under the terms of the derivative contract. To mitigate this risk, the hedging instruments are placed with a number of counterparties whom Devon believes are acceptable credit risks. It is Devon’s policy to enter into derivative contracts only with investment-grade rated counterparties deemed by management to be competent and competitive market makers. Additionally, Devon’s derivative contracts generally contain provisions that provide for collateral payments, if Devon’s or its counterparty’s credit rating falls below certain credit rating levels.

As of June 30, 2017, Devon held $34 million of cash collateral, which represented the estimated fair value of certain derivative positions in excess of Devon’s credit guidelines and is reported in other current liabilities in the accompanying consolidated balance sheets. As of December 31, 2016, Devon held no collateral from counterparties.

12

 


Table of Contents

DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

 

Commodity Derivatives

As of June 30, 2017, Devon had the following open oil derivative positions. The first table presents Devon’s oil derivatives that settle against the average of the prompt month NYMEX WTI futures price. The second table presents Devon’s oil derivatives that settle against the respective indices noted within the table.

 

 

Price Swaps

 

 

Price Collars

 

Period

 

Volume

(Bbls/d)

 

 

Weighted

Average

Price ($/Bbl)

 

 

Volume

(Bbls/d)

 

 

Weighted

Average Floor

Price ($/Bbl)

 

 

Weighted

Average

Ceiling Price

($/Bbl)

 

Q3-Q4 2017

 

 

76,380

 

 

$

54.22

 

 

 

66,500

 

 

$

45.76

 

 

$

58.01

 

Q1-Q4 2018

 

 

11,592

 

 

$

52.15

 

 

 

17,921

 

 

$

46.77

 

 

$

56.77

 

 

 

 

Oil Basis Swaps

 

Period

 

Index

 

Volume (Bbls/d)

 

 

Weighted Average

Differential to WTI

($/Bbl)

 

Q3-Q4 2017

 

Midland Sweet

 

 

20,000

 

 

$

(0.41

)

Q3-Q4 2017

 

Western Canadian Select

 

 

81,745

 

 

$

(14.47

)

Q1-Q4 2018

 

Western Canadian Select

 

 

32,748

 

 

$

(15.29

)

 

As of June 30, 2017, Devon had the following open natural gas derivative positions. The first table presents Devon’s natural gas derivatives that settle against the Inside FERC first of the month Henry Hub index. The second table presents Devon’s natural gas derivatives that settle against the respective indices noted within the table.

 

 

 

Price Swaps

 

 

Price Collars

 

Period

 

Volume (MMBtu/d)

 

 

Weighted Average Price ($/MMBtu)

 

 

Volume (MMBtu/d)

 

 

Weighted Average Floor Price ($/MMBtu)

 

 

Weighted Average

Ceiling Price ($/MMBtu)

 

Q3-Q4 2017

 

 

235,000

 

 

$

3.25

 

 

 

435,000

 

 

$

3.03

 

 

$

3.42

 

Q1-Q4 2018

 

 

115,107

 

 

$

3.13

 

 

 

66,433

 

 

$

3.19

 

 

$

3.52

 

 

 

 

Natural Gas Basis Swaps

 

Period

 

Index

 

Volume

(MMBtu/d)

 

 

Weighted Average

Differential to

Henry Hub

($/MMBtu)

 

Q3-Q4 2017

 

Panhandle Eastern Pipe Line

 

 

150,000

 

 

$

(0.34

)

Q3-Q4 2017

 

El Paso Natural Gas

 

 

80,000

 

 

$

(0.13

)

Q3-Q4 2017

 

Houston Ship Channel

 

 

35,000

 

 

$

0.06

 

Q3-Q4 2017

 

Transco Zone 4

 

 

205,000

 

 

$

0.03

 

Q1-Q4 2018

 

Panhandle Eastern Pipe Line

 

 

50,000

 

 

$

(0.29

)

 

As of June 30, 2017, Devon had the following open NGL derivative positions. Devon’s NGL positions settle against the average of the prompt month OPIS Mont Belvieu, Texas index.

 

 

 

 

 

Price Swaps

 

 

Price Collars

 

Period

 

Product

 

Volume (Bbls/d)

 

 

Weighted Average Price ($/Bbl)

 

 

Volume (Bbls/d)

 

 

Weighted Average Floor Price ($/Bbl)

 

 

Weighted Average Ceiling Price ($/Bbl)

 

Q3-Q4 2017

 

Propane

 

 

1,000

 

 

$

29.61

 

 

 

1,000

 

 

$

27.83

 

 

$

29.93

 

13

 


Table of Contents

DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

 

Interest Rate Derivatives

As of June 30, 2017, Devon had the following open interest rate derivative positions:

 

Notional

 

 

Rate Received

 

 

Rate Paid

 

 

Expiration

(Millions)

 

 

 

 

 

 

 

 

 

 

 

$

750

 

 

Three Month LIBOR

 

 

 

2.98%

 

 

December 2048 (1)

$

100

 

 

 

1.76%

 

 

Three Month LIBOR

 

 

January 2019

 

(1)

Mandatory settlement in December 2018.

 

Financial Statement Presentation

The following table presents the net gains and losses by derivative financial instrument type followed by the corresponding individual consolidated comprehensive statements of earnings caption.

 

 

 

Three Months

Ended June 30,

 

 

Six Months

Ended June 30,

 

 

 

2017

 

 

2016

 

 

2017

 

 

2016

 

 

 

(Millions)

 

Commodity derivatives:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Oil, gas and NGL derivatives

 

$

126

 

 

$

(142

)

 

$

358

 

 

$

(109

)

Marketing and midstream revenues

 

 

4

 

 

 

(6

)

 

 

8

 

 

 

(6

)

Interest rate derivatives:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Other nonoperating items

 

 

(20

)

 

 

(71

)

 

 

(15

)

 

 

(143

)

Foreign currency derivatives:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Other nonoperating items

 

 

 

 

 

(4

)

 

 

 

 

 

(159

)

Net gains (losses) recognized

 

$

110

 

 

$

(223

)

 

$

351

 

 

$

(417

)

 

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

 

 

 

June 30, 2017

 

 

December 31, 2016

 

 

 

(Millions)

 

Commodity derivative assets:

 

 

 

 

 

 

 

 

Other current assets

 

$

189

 

 

$

9

 

Other long-term assets

 

 

14

 

 

 

1

 

Interest rate derivative assets:

 

 

 

 

 

 

 

 

Other current assets

 

 

1

 

 

 

1

 

Other long-term assets

 

 

1

 

 

 

 

Total derivative assets

 

$

205

 

 

$

11

 

Commodity derivative liabilities:

 

 

 

 

 

 

 

 

Other current liabilities

 

$

47

 

 

$

187

 

Other long-term liabilities

 

 

1

 

 

 

16

 

Interest rate derivative liabilities:

 

 

 

 

 

 

 

 

Other current liabilities

 

 

1

 

 

 

 

Other long-term liabilities

 

 

57

 

 

 

41

 

Total derivative liabilities

 

$

106

 

 

$

244

 

 

14

 


Table of Contents

DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

 

4.

Share-Based Compensation

In the second quarter of 2017, Devon’s stockholders approved the 2017 Plan. The 2017 Plan replaces the 2015 Plan. From the effective date of the 2017 Plan, no further awards may be made under the 2015 Plan, and awards previously granted will continue to be governed by the terms of the respective award documents. Subject to the terms of the 2017 Plan, awards may be made for a total of 33.5 million shares of Devon common stock, plus the number of shares available for issuance under the 2015 Plan (including shares subject to outstanding awards under the 2015 Plan that are transferred to the 2017 Plan in accordance with its terms). The 2017 Plan authorizes the Compensation Committee, which consists of independent, non-management members of Devon’s Board of Directors, to grant nonqualified and incentive stock options, restricted stock awards or units, Canadian restricted stock units, performance units and stock appreciation rights to eligible employees. The 2017 Plan also authorizes the grant of nonqualified stock options, restricted stock awards or units and stock appreciation rights to non-employee directors. To calculate the number of shares that may be granted in awards under the 2017 Plan, options and stock appreciation rights represent one share and other awards represent 2.3 shares.

The following table presents the effects of share-based compensation included in Devon’s accompanying consolidated comprehensive statements of earnings. Gross G&A expense for the first six months of 2017 and 2016 includes $21 million and $12 million, respectively, of unit-based compensation related to grants made under EnLink’s long-term incentive plans.

The vesting for certain share-based awards was accelerated in 2016 in conjunction with the reduction of workforce described in Note 6. For the six months ended June 30, 2016, approximately $67 million of associated expense for these accelerated awards is included in restructuring and transaction costs in the accompanying consolidated comprehensive statements of earnings.

 

 

 

Six Months Ended June 30,

 

 

 

2017

 

 

2016

 

 

 

(Millions)

 

Gross G&A for share-based compensation

 

$

100

 

 

$

80

 

Share-based compensation expense capitalized pursuant to

   the full cost method of accounting for oil and gas properties

 

$

20

 

 

$

21

 

Related income tax benefit

 

$

2

 

 

$

2

 

 

Under its approved long-term incentive plan, Devon granted share-based awards to certain employees in the first six months of 2017. The following table presents a summary of Devon’s unvested restricted stock awards and units, performance-based restricted stock awards and performance share units granted under the plan.

 

 

 

Restricted Stock

 

 

Performance-Based

 

 

Performance

 

 

 

Awards and Units

 

 

Restricted Stock Awards

 

 

Share Units

 

 

 

Awards and

Units

 

 

Weighted

Average

Grant-Date

Fair Value

 

 

Awards

 

 

Weighted

Average

Grant-Date

Fair Value

 

 

Units

 

 

 

 

 

Weighted

Average

Grant-Date

Fair Value

 

 

 

(Thousands, except fair value data)

 

Unvested at 12/31/16

 

 

6,407

 

 

$

34.40

 

 

 

585

 

 

$

37.60

 

 

 

2,604

 

 

 

 

 

$

46.66

 

Granted

 

 

2,683

 

 

$

44.90

 

 

 

223

 

 

$

44.85

 

 

 

1,010

 

 

 

 

 

$

52.58

 

Vested

 

 

(2,168

)

 

$

39.38

 

 

 

(225

)

 

$

41.04

 

 

 

(832

)

 

 

 

 

$

78.19

 

Forfeited

 

 

(149

)

 

$

35.91

 

 

 

 

 

$

 

 

 

(7

)

 

 

 

 

$

37.41

 

Unvested at 6/30/17

 

 

6,773

 

 

$

36.94

 

 

 

583

 

 

$

39.04

 

 

 

2,775

 

 

(1

)

 

$

41.22

 

 

(1)

A maximum of 5.5 million common shares could be awarded based upon Devon’s final TSR ranking relative to Devon’s peer group established under applicable award agreements.

15

 


Table of Contents

DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

 

The following table presents the assumptions related to the performance share units granted in 2017, as indicated in the previous summary table.

 

 

 

2017

 

Grant-date fair value

 

$

51.05

 

 

 

$

53.12

 

Risk-free interest rate

 

1.50%

 

Volatility factor

 

45.8%

 

Contractual term (years)

 

2.89

 

 

The following table presents a summary of the unrecognized compensation cost and the related weighted average recognition period associated with unvested awards and units as of June 30, 2017.

 

 

 

 

 

 

 

Performance-Based

 

 

 

 

 

 

 

Restricted Stock

 

 

Restricted Stock

 

 

Performance

 

 

 

Awards and Units

 

 

Awards

 

 

Share Units

 

Unrecognized compensation cost (millions)

 

$

185

 

 

$

8

 

 

$

42

 

Weighted average period for recognition (years)

 

 

2.7

 

 

 

2.0

 

 

 

2.1

 

EnLink Share-Based Awards

In March 2017, the General Partner and EnLink issued restricted incentive units as bonus payments to officers and certain employees. The combined grant fair value was $10 million, and the total cost was recognized in the first quarter of 2017 due to the awards vesting immediately.

The following table presents a summary of the unrecognized compensation cost and the related weighted average recognition period associated with the General Partner’s and EnLink’s unvested restricted incentive units and performance units as of June 30, 2017.

 

 

 

General Partner

 

 

EnLink

 

 

 

Restricted

 

 

Performance

 

 

Restricted

 

 

Performance

 

 

 

Incentive Units

 

 

Units

 

 

Incentive Units

 

 

Units

 

Unrecognized compensation cost (millions)

 

$

17

 

 

$

7

 

 

$

18

 

 

$

7

 

Weighted average period for recognition (years)

 

 

1.9

 

 

 

2.1

 

 

 

1.9

 

 

 

2.1

 

 

 

5.

Asset Impairments

Oil and Gas Impairments

Under the full cost method of accounting, capitalized costs of oil and gas properties, net of accumulated DD&A and deferred income taxes, may not exceed the full cost “ceiling” at the end of each quarter. The ceiling is calculated separately for each country and is based on the present value of estimated future net cash flows from proved oil and gas reserves, discounted at 10% per annum, net of related tax effects. Estimated future net cash flows are calculated using end-of-period costs and an unweighted arithmetic average of commodity prices in effect on the first day of each of the previous 12 months.

Devon recognized $885 million and $2.5 billion in oil and gas asset impairments for its U.S. operations and $612 million and $1.2 billion for its Canadian operations for the three months ended and six months ended June 30, 2016, respectively. The oil and gas impairments resulted from declines in the U.S. and Canada full cost ceilings. The lower ceiling values resulted primarily from significant decreases in the 12-month average trailing prices for oil, bitumen, gas and NGLs, which significantly reduced proved reserves values and, to a lesser degree, proved reserves.

16

 


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DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

 

EnLink Goodwill Impairments

In the first quarter of 2016, EnLink recognized $873 million in goodwill impairments. See Note 12 for additional details.

 

6.      Restructuring and Transaction Costs

The following table summarizes restructuring and transaction costs presented in the accompanying consolidated comprehensive statement of earnings.

 

 

June 30, 2016

 

 

 

Three Months Ended

 

 

Six Months Ended

 

 

 

(Millions)

 

2016 reduction in workforce:

 

 

 

 

 

 

 

 

Employee related costs

 

$

2

 

 

$

236

 

Lease obligations

 

 

17

 

 

 

17

 

Asset impairments

 

 

3

 

 

 

3

 

Transaction costs

 

 

2

 

 

 

15

 

Restructuring and transaction costs

 

$

24

 

 

$

271

 

The following table summarizes Devon’s restructuring liabilities.

 

 

Other

 

 

Other

 

 

 

 

 

 

 

Current

 

 

Long-term

 

 

 

 

 

 

 

Liabilities

 

 

Liabilities

 

 

Total

 

 

 

(Millions)

 

Balance as of December 31, 2016

 

$

48

 

 

$

62

 

 

$

110

 

Changes due to 2016 workforce reductions

 

 

(24

)

 

 

 

 

 

(24

)

Changes related to prior years' restructurings

 

 

7

 

 

 

(12

)

 

 

(5

)

Balance as June 30, 2017

 

$

31

 

 

$

50

 

 

$

81

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Balance as of December 31, 2015

 

$

13

 

 

$

63

 

 

$

76

 

Changes due to 2016 workforce reductions

 

 

107

 

 

 

13

 

 

 

120

 

Changes related to prior years' restructurings

 

 

3

 

 

 

(6

)

 

 

(3

)

Balance as of June 30, 2016

 

$

123

 

 

$

70

 

 

$

193

 

Reduction in Workforce

In the first six months of 2016, Devon recognized $236 million in employee-related costs associated with a reduction in workforce. Of these employee-related costs, approximately $67 million resulted from accelerated vesting of share-based grants, which are noncash charges. Additionally, approximately $30 million resulted from estimated settlements of defined retirement benefits.

As a result of the reduction of workforce, Devon ceased using certain office space that was subject to non-cancellable operating lease arrangements. Devon recognized restructuring costs that represent the present value of its future obligations under the leases and impairment charges for leasehold improvements and furniture associated with the office space it ceased using.

Transaction Costs

In the first six months of 2016, Devon and EnLink recognized transaction costs primarily associated with the closing of the acquisitions discussed in Note 2.

 

 

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Table of Contents

DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

 

7.

Income Taxes

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

 

 

 

Three Months Ended June 30,

 

 

Six Months Ended June 30,

 

 

 

2017

 

 

2016

 

 

2017

 

 

2016

 

 

 

(Millions)

 

Current income tax expense (benefit)

 

$

12

 

 

$

(3

)

 

$

32

 

 

$

(13

)

Deferred income tax benefit

 

 

(5

)

 

 

(179

)

 

 

(6

)

 

 

(386

)

Total income tax expense (benefit)

 

$

7

 

 

$

(182

)

 

$

26

 

 

$

(399

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

U.S. statutory income tax rate

 

 

35

%

 

 

35

%

 

 

35

%

 

 

35

%

Deferred tax asset valuation allowance

 

 

(27

%)

 

 

(27

%)

 

 

(29

%)

 

 

(24

%)

Non-deductible goodwill impairments

 

 

0

%

 

 

0

%

 

 

0

%

 

 

(6

%)

Taxation on Canadian operations

 

 

0

%

 

 

(3

%)

 

 

0

%

 

 

(2

%)

State income taxes

 

 

0

%

 

 

2

%

 

 

0

%

 

 

1

%

Other

 

 

(6

%)

 

 

3

%

 

 

(4

%)

 

 

3

%

Effective income tax rate

 

 

2

%

 

 

10

%

 

 

2

%

 

 

7

%

 

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

Throughout 2016 and through the first six months of 2017, Devon continued to maintain a 100% valuation allowance against its U.S. deferred tax assets resulting from prior year cumulative financial losses largely due to full cost impairments. Devon provided an additional $1.3 billion to the U.S. segment valuation allowance in the first six months of 2016 based on the financial loss recorded during the period. Devon reduced its U.S. segment valuation allowance by $320 million in the first six months of 2017 based on the financial income recorded during the period. Furthermore, a partial allowance continues to be held against certain Canadian segment deferred tax assets.

In the first quarter of 2016, EnLink recorded goodwill impairments totaling $873 million. These impairments are not deductible for purposes of calculating income tax and, therefore, have an impact on the effective tax rate.

Devon is under audit in the U.S. and various foreign jurisdictions as part of its normal course of business. The timing of resolution of income tax examinations is uncertain as are the amounts and timing of tax payments that are part of any audit settlement process. Devon believes that within the next 12 months it is reasonably possible that certain tax examinations will be resolved by settlement with the taxing authorities.

 

 

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Table of Contents

DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

 

8.

Net Earnings (Loss) Per Share Attributable to Devon

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

 

 

 

Three Months Ended June 30,

 

 

Six Months Ended June 30,

 

 

 

2017

 

 

2016

 

 

2017

 

 

2016

 

 

 

(Millions, except per share amounts)

 

Net earnings (loss):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Net earnings (loss) attributable to Devon

 

$

425

 

 

$

(1,570

)

 

$

990

 

 

$

(4,626

)

Attributable to participating securities

 

 

(5

)

 

 

(1

)

 

 

(11

)

 

 

(1

)

Basic and diluted earnings (loss)

 

$

420

 

 

$

(1,571

)

 

$

979

 

 

$

(4,627

)

Common shares:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Common shares outstanding - total

 

 

526

 

 

 

524

 

 

 

525

 

 

 

502

 

Attributable to participating securities

 

 

(6

)

 

 

(6

)

 

 

(6

)

 

 

(6

)

Common shares outstanding - basic

 

 

520

 

 

 

518

 

 

 

519

 

 

 

496

 

Dilutive effect of potential common shares issuable

 

 

3

 

 

 

 

 

 

3

 

 

 

 

Common shares outstanding - diluted

 

 

523

 

 

 

518

 

 

 

522

 

 

 

496

 

Net earnings (loss) per share attributable to Devon:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Basic

 

$

0.81

 

 

$

(3.04

)

 

$

1.88

 

 

$

(9.33

)

Diluted

 

$

0.80

 

 

$

(3.04

)

 

$

1.87

 

 

$

(9.33

)

Antidilutive options (1)

 

 

2

 

 

 

3

 

 

 

2

 

 

 

3

 

 

(1)

Amounts represent options to purchase shares of Devon’s common stock that are excluded from the diluted net earnings (loss) per share calculations because the options are antidilutive.

 

9.

Other Comprehensive Earnings

Components of other comprehensive earnings consist of the following:

 

 

 

Three Months Ended June 30,

 

 

Six Months Ended June 30,

 

 

 

2017

 

 

2016

 

 

2017

 

 

2016

 

 

 

(Millions)

 

Foreign currency translation:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Beginning accumulated foreign currency translation

 

$

454

 

 

$

447

 

 

$

456

 

 

$

424

 

Change in cumulative translation adjustment

 

 

13

 

 

 

2

 

 

 

14

 

 

 

53

 

Income tax benefit (expense)

 

 

(11

)

 

 

1

 

 

 

(14

)

 

 

(27

)

Ending accumulated foreign currency translation

 

 

456

 

 

 

450

 

 

 

456

 

 

 

450

 

Pension and postretirement benefit plans:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Beginning accumulated pension and postretirement benefits

 

 

(167

)

 

 

(190

)

 

 

(172

)

 

 

(194

)

Recognition of net actuarial loss and prior

   service cost in earnings (1)

 

 

4

 

 

 

8

 

 

 

9

 

 

 

13

 

Income tax expense

 

 

 

 

 

(3

)

 

 

 

 

 

(4

)

Ending accumulated pension and postretirement benefits

 

 

(163

)

 

 

(185

)

 

 

(163

)

 

 

(185

)

Other

 

 

(2

)

 

 

 

 

 

(2

)

 

 

 

Accumulated other comprehensive earnings, net of tax

 

$

291

 

 

$

265

 

 

$

291

 

 

$

265

 

 

(1)

These accumulated other comprehensive earnings components are included in the computation of net periodic benefit cost, which is a component of G&A on the accompanying consolidated comprehensive statements of earnings. See Note 16 for additional details.

 

 

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Table of Contents

DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

 

10.

Supplemental Information to Statements of Cash Flows

 

 

 

Three Months Ended June 30,

 

 

Six Months Ended June 30,

 

 

 

2017

 

 

2016

 

 

2017

 

 

2016

 

 

 

(Millions)

 

Net change in working capital accounts, net of assets and

   liabilities assumed:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Accounts receivable

 

$

82

 

 

$

(140

)

 

$

130

 

 

$

6

 

Income taxes receivable

 

 

7

 

 

 

(14

)

 

 

8

 

 

 

101

 

Other current assets

 

 

(33

)

 

 

(107

)

 

 

(55

)

 

 

144

 

Accounts payable

 

 

46

 

 

 

(30

)

 

 

50

 

 

 

(151

)

Revenues and royalties payable

 

 

(44

)

 

 

95

 

 

 

29

 

 

 

(6

)

Other current liabilities

 

 

14

 

 

 

53

 

 

 

(75

)

 

 

(23

)

Net change in working capital

 

$

72

 

 

$

(143

)

 

$

87

 

 

$

71

 

Interest paid (net of capitalized interest)

 

$

144

 

 

$

174

 

 

$

236

 

 

$

289

 

Income taxes paid (received)

 

$

(4

)

 

$

5

 

 

$

(1

)

 

$

(123

)

 

Devon’s acquisition of certain STACK assets during the first three months of 2016 included the noncash issuance of Devon common stock. See Note 2 for additional details.

EnLink’s acquisition of Anadarko Basin gathering and processing midstream assets during the first three months of 2016 included noncash issuance of General Partner common units. See Note 2 for additional details.

 

 

11.

Accounts Receivable

Components of accounts receivable include the following:

 

 

 

June 30, 2017

 

 

December 31, 2016

 

 

 

(Millions)

 

Oil, gas and NGL sales

 

$

440

 

 

$

487

 

Joint interest billings

 

 

101

 

 

 

110

 

Marketing and midstream revenues

 

 

665

 

 

 

708

 

Other

 

 

58

 

 

 

69

 

Gross accounts receivable

 

 

1,264

 

 

 

1,374

 

Allowance for doubtful accounts

 

 

(16

)

 

 

(18

)

Net accounts receivable

 

$

1,248

 

 

$

1,356

 

 


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Table of Contents

DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

 

 

12.

Goodwill and Other Intangible Assets

Goodwill

Devon performs an annual impairment test of goodwill at October 31, or more frequently if events or changes in circumstances indicate that the carrying value of a reporting unit may not be recoverable. Sustained weakness in the overall energy sector driven by low commodity prices, together with a decline in EnLink’s unit price, caused a noncash goodwill impairment of $873 million in the first quarter of 2016. This consisted of a full impairment charge of $93 million related to EnLink’s Crude and Condensate reporting unit and partial impairments to EnLink’s Texas and General Partner reporting units of $473 million and $307 million, respectively.

Other Intangible Assets

The following table presents other intangible assets reported in other long-term assets in the accompanying consolidated balance sheets.

 

 

 

June 30, 2017

 

 

December 31, 2016

 

 

 

(Millions)

 

Customer relationships

 

$

1,796

 

 

$

1,796

 

Accumulated amortization

 

 

(231

)

 

 

(172

)

Net intangibles

 

$

1,565

 

 

$

1,624

 

 

The weighted-average amortization period for other intangible assets is 14 years. Amortization expense for intangibles was $30 million for both the three months ended June 30, 2017 and 2016, respectively, and $59 million and $58 million for the six months ended June 30, 2017 and 2016, respectively. The remaining amortization expense is estimated to be $118 million for each of the next five years.

 

 

13.

Other Current Liabilities

Components of other current liabilities include the following:

 

 

June 30, 2017

 

 

December 31, 2016

 

 

(Millions)

 

Installment payment - see Note 2

$

237

 

 

$

249

 

Derivative liabilities

 

48

 

 

 

187

 

Accrued interest payable

 

133

 

 

 

130

 

Restructuring liabilities

 

31

 

 

 

48

 

Other

 

442

 

 

 

452

 

Other current liabilities

$

891

 

 

$

1,066

 

 

21

 


Table of Contents

DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

 

 

14.

Debt and Related Expenses

A summary of debt is as follows:

 

 

June 30, 2017

 

 

December 31, 2016

 

 

 

(Millions)

 

Devon debt:

 

 

 

 

 

 

 

 

Debentures and notes

 

$

6,933

 

 

$

6,933

 

Net discount on debentures and notes

 

 

(30

)

 

 

(30

)

Debt issuance costs

 

 

(42

)

 

 

(44

)

Total Devon debt

 

 

6,861

 

 

 

6,859

 

EnLink debt:

 

 

 

 

 

 

 

 

Credit facilities

 

 

231

 

 

 

148

 

Debentures and notes

 

 

3,500

 

 

 

3,163

 

Net premium (discount) on debentures and notes

 

 

(6

)

 

 

9

 

Debt issuance costs

 

 

(28

)

 

 

(25

)

Total EnLink debt

 

 

3,697

 

 

 

3,295

 

Total long-term debt

 

$

10,558

 

 

$

10,154

 

  Credit Lines

Devon has a $3.0 billion Senior Credit Facility. As of June 30, 2017, Devon had $58 million in outstanding letters of credit under the Senior Credit Facility. There were no outstanding borrowings under the Senior Credit Facility at June 30, 2017. The Senior Credit Facility contains only one material financial covenant. This covenant requires Devon’s ratio of total funded debt to total capitalization, as defined in the credit agreement, to be no greater than 65%. Under the terms of the credit agreement, total capitalization is adjusted to add back noncash financial write-downs such as full cost ceiling impairments or goodwill impairments. As of June 30, 2017, Devon was in compliance with this covenant with a debt-to-capitalization ratio of 19.3%.

EnLink Debt

All of EnLink’s and the General Partner’s debt is non-recourse to Devon.

EnLink has a $1.5 billion unsecured revolving credit facility. As of June 30, 2017, there were $9 million in outstanding letters of credit and $166 million in outstanding borrowings at an average rate of 2.8% under the $1.5 billion credit facility. The General Partner has a $250 million secured revolving credit facility. As of June 30, 2017, the General Partner had $65 million in outstanding borrowings at an average rate of 3.2%. EnLink and the General Partner were in compliance with all financial covenants in their respective credit facilities as of June 30, 2017.

In May 2017, EnLink issued $500 million of 5.45% unsecured senior notes due in 2047. The proceeds were used to repay outstanding borrowings under its revolving credit facility and for general partnership purposes. Additionally, in June 2017, EnLink redeemed its $163 million 7.125% senior unsecured notes due in 2022. EnLink redeemed the notes at 103.6% of the principal amount, plus accrued unpaid interest, for aggregate cash consideration of $174 million, which resulted in a gain on extinguishment of debt of $9 million for both the three and six months ended June 30, 2017. The gain is included in net financing costs in the consolidated comprehensive statement of earnings.

22

 


Table of Contents

DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

 

 

15.

Asset Retirement Obligations

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

 

 

 

Six Months Ended June 30,

 

 

 

2017

 

 

2016

 

 

 

(Millions)

 

Asset retirement obligations as of beginning of period

 

$

1,272

 

 

$

1,414

 

Liabilities incurred and assumed through acquisitions

 

 

15

 

 

 

15

 

Liabilities settled and divested

 

 

(26

)

 

 

(51

)

Revision of estimated obligation

 

 

(184

)

 

 

70

 

Accretion expense on discounted obligation

 

 

31

 

 

 

39

 

Foreign currency translation adjustment

 

 

14

 

 

 

30

 

Asset retirement obligations as of end of period

 

 

1,122

 

 

 

1,517

 

Less current portion

 

 

44

 

 

 

44

 

Asset retirement obligations, long-term

 

$

1,078

 

 

$

1,473

 

 

          During the first quarter of 2017, Devon reduced its estimated asset retirement obligations by $184 million primarily due to changes in the assumed inflation rate and retirement dates for its oil and gas assets.

 

16.

Retirement Plans

The following table presents the components of net periodic benefit cost for Devon’s pension and postretirement benefit plans.

 

 

 

Pension Benefits

 

 

Postretirement Benefits

 

 

 

Three Months Ended

 

 

Six Months Ended

 

 

Three Months Ended

 

 

Six Months Ended

 

 

 

June 30,

 

 

June 30,

 

 

June 30,

 

 

June 30,

 

 

 

2017

 

 

2016

 

 

2017

 

 

2016

 

 

2017

 

 

2016

 

 

2017

 

 

2016

 

 

 

(Millions)

 

Service cost

 

$

4

 

 

$

3

 

 

$

8

 

 

$

9

 

 

$

 

 

$

 

 

$

 

 

$

 

Interest cost

 

 

11

 

 

 

11

 

 

 

21

 

 

 

23

 

 

 

 

 

 

 

 

 

 

 

 

 

Expected return on plan assets

 

 

(14

)

 

 

(13

)

 

 

(27

)

 

 

(26

)

 

 

 

 

 

 

 

 

 

 

 

 

Amortization of prior service cost (1)

 

 

 

 

 

1

 

 

 

1

 

 

 

1

 

 

 

(1

)

 

 

 

 

 

(1

)

 

 

(1

)

Net actuarial loss (1)

 

 

5

 

 

 

7

 

 

 

9

 

 

 

13

 

 

 

 

 

 

 

 

 

 

 

 

 

Net periodic benefit cost (2)

 

$

6

 

 

$

9

 

 

$

12

 

 

$

20

 

 

$

(1

)

 

$

 

 

$

(1

)

 

$

(1

)

 

(1)

These net periodic benefit costs were reclassified out of other comprehensive earnings in the current period.

(2)    Net periodic benefit cost is a component of G&A in the accompanying consolidated comprehensive statements of earnings.

 

 

17.

Stockholders’ Equity

Common Stock Issued

In January 2016, Devon issued approximately 23 million shares of common stock in conjunction with the STACK asset acquisition discussed in Note 2.

In February 2016, Devon issued 79 million shares of common stock to the public, inclusive of 10 million shares sold as part of the underwriters’ option. Net proceeds from the offering were $1.5 billion.

23

 


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DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

 

Dividends

The table below summarizes the dividends Devon paid on its common stock.

 

Amounts

 

 

Rate

 

 

(Millions)

 

 

(Per Share)

 

Quarter Ended 2017:

 

 

 

 

 

 

 

First quarter 2017

$

32

 

 

$

0.06

 

Second quarter 2017

 

33

 

 

$

0.06

 

Total year-to-date

$

65

 

 

 

 

 

Quarter Ended 2016:

 

 

 

 

 

 

 

First quarter 2016

$

125

 

 

$

0.24

 

Second quarter 2016

 

33

 

 

$

0.06

 

Total year-to-date

$

158

 

 

 

 

 

In response to the depressed commodity price environment, Devon reduced its quarterly dividend to $0.06 per share in the second quarter of 2016.

 

18.

Noncontrolling Interests

Subsidiary Equity Transactions

EnLink has the ability to sell common units through an “at the market” equity offering program. During the first six months of 2017, EnLink issued and sold 4 million common units though its “at the market” program and generated $72 million in net proceeds. During the first quarter of 2016, EnLink issued preferred units in conjunction with its acquisition of Anadarko Basin gathering and processing midstream assets as discussed in Note 2. As of June 30, 2017, Devon’s ownership interest in EnLink was 23%, excluding the interest held by the General Partner. Devon’s ownership interest in the General Partner as of June 30, 2017 was 64%. The net gains and losses and related income taxes resulting from these transactions have been recorded as an adjustment to equity, with the change in ownership reflected as an adjustment to noncontrolling interests.

Distributions to Noncontrolling Interests

EnLink and the General Partner distributed $163 million and $147 million to non-Devon unitholders during the first six months of 2017 and 2016, respectively.

 

 

19.

Commitments and Contingencies

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

Royalty Matters

Numerous oil and natural gas producers and related parties, including Devon, have been named in various lawsuits alleging royalty underpayments. The suits allege that the producers and related parties used below-market prices, made improper deductions, used improper measurement techniques and entered into gas purchase and processing arrangements with affiliates that resulted in underpayment of royalties in connection with oil, natural gas and NGLs produced and sold. Devon is also involved in governmental agency proceedings and is subject to related contracts and regulatory controls in the ordinary course of business, some that may lead to additional royalty claims. Devon does not currently believe that it is subject to material exposure with respect to such royalty matters.

24

 


Table of Contents

DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

 

Environmental Matters

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

Other Matters

Devon is involved in other various legal proceedings incidental to its business. However, to Devon’s knowledge, there were no other material pending legal proceedings to which Devon is a party or to which any of its property is subject.

 

 

20.

Fair Value Measurements

The following table provides carrying value and fair value measurement information for certain of Devon’s financial assets and liabilities. None of the items below are measured using Level 3 inputs. The carrying values of cash, accounts receivable, other current receivables, accounts payable, other current payables and accrued expenses included in the accompanying consolidated balance sheets approximated fair value at June 30, 2017 and December 31, 2016. Therefore, such financial assets and liabilities are not presented in the following table. Additionally, the fair values of oil and gas assets, goodwill and other intangible assets and related impairments are measured as of the impairment date using Level 3 inputs. More information on these items is provided in Note 5 and Note 12, respectively.

 

 

 

 

 

 

 

 

 

 

 

Fair Value

 

 

 

 

 

 

 

 

 

 

 

Measurements Using:

 

 

 

Carrying

 

 

Total Fair

 

 

Level 1

 

 

Level 2

 

 

 

Amount

 

 

Value

 

 

Inputs

 

 

Inputs

 

 

 

(Millions)

 

June 30, 2017 assets (liabilities):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Cash equivalents

 

$

1,868

 

 

$

1,868

 

 

$

1,653

 

 

$

215

 

Commodity derivatives

 

$

203

 

 

$

203

 

 

$

 

 

$

203

 

Commodity derivatives

 

$

(48

)

 

$

(48

)

 

$

 

 

$

(48

)

Interest rate derivatives

 

$

2

 

 

$

2

 

 

$

 

 

$

2

 

Interest rate derivatives

 

$

(58

)

 

$

(58

)

 

$

 

 

$

(58

)

Debt

 

$

(10,558

)

 

$

(11,446

)

 

$

 

 

$

(11,446

)

Installment payment

 

$

(237

)

 

$

(238

)

 

$

 

 

$

(238

)

Capital lease obligations

 

$

(5

)

 

$

(4

)

 

$

 

 

$

(4

)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

December 31, 2016 assets (liabilities):

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Cash equivalents

 

$

1,542

 

 

$

1,542

 

 

$

1,298

 

 

$

244

 

Commodity derivatives

 

$

10

 

 

$

10

 

 

$

 

 

$

10

 

Commodity derivatives

 

$

(203

)

 

$

(203

)

 

$

 

 

$

(203

)

Interest rate derivatives

 

$

1

 

 

$

1

 

 

$

 

 

$

1

 

Interest rate derivatives

 

$

(41

)

 

$

(41

)

 

$

 

 

$

(41

)

Debt

 

$

(10,154

)

 

$

(10,760

)

 

$

 

 

$

(10,760

)

Installment payment

 

$

(473

)

 

$

(477

)

 

$

 

 

$

(477

)

Capital lease obligations

 

$

(7

)

 

$

(6

)

 

$

 

 

$

(6

)

 

25

 


Table of Contents

DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

 

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

Level 1 Fair Value Measurements

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

Level 2 Fair Value Measurements

Cash equivalents – Amounts consist primarily of commercial paper and Canadian agency and provincial securities investments. The fair value approximates the carrying value.

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

Debt – Devon’s debt instruments do not actively trade in an established market. The fair values of its debt are estimated based on rates available for debt with similar terms and maturity. The fair values of commercial paper and credit facility balances are the carrying values.

Installment payment – The fair value of the EnLink installment payment was based on Level 2 inputs from third-party market quotations.

Capital lease obligations – The fair value was calculated using inputs from third-party banks.

 

 

21.

Segment Information

Devon manages its operations through distinct operating segments, which are defined primarily by geographic areas. For financial reporting purposes, Devon aggregates its U.S. operating segments into one reporting segment due to the similar nature of the businesses. However, Devon’s Canadian E&P operating segment is reported as a separate reporting segment primarily due to the significant differences between the U.S. and Canadian regulatory environments. Devon’s U.S. and Canadian segments are both primarily engaged in oil and gas E&P activities.

Devon considers EnLink, combined with the General Partner, to be an operating segment that is distinct from the U.S. and Canadian operating segments. EnLink’s operations consist of midstream assets and operations located across the U.S. Additionally, EnLink has a management team that is primarily responsible for capital and resource allocation decisions. Therefore, EnLink is presented as a separate reporting segment.

26

 


Table of Contents

DEVON ENERGY CORPORATION AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS – (Continued)

(Unaudited)

 

 

 

 

U.S.

 

 

Canada

 

 

EnLink

 

 

Eliminations

 

 

Total

 

 

 

(Millions)

 

Three Months Ended June 30, 2017:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Revenues from external customers

 

$

1,891

 

 

$

274

 

 

$

1,094

 

 

$

 

 

$

3,259

 

Intersegment revenues

 

$

 

 

$

 

 

$

170

 

 

$

(170

)

 

$

 

Depreciation, depletion and amortization

 

$

180

 

 

$

64

 

 

$

137

 

 

$

 

 

$

381

 

Interest expense

 

$

81

 

 

$

11

 

 

$

39

 

 

$

(12

)

 

$

119

 

Asset impairments

 

$

 

 

$

 

 

$

 

 

$

 

 

$

 

Earnings before income taxes

 

$

409

 

 

$

12

 

 

$

37

 

 

$

 

 

$

458

 

Income tax expense

 

$

2

 

 

$

1

 

 

$

4

 

 

$

 

 

$

7

 

Net earnings

 

$

407

 

 

$

11

 

 

$

33

 

 

$

 

 

$

451

 

Net earnings attributable to noncontrolling interests

 

$

 

 

$

 

 

$

26

 

 

$

 

 

$

26

 

Net earnings attributable to Devon

 

$

407

 

 

$

11

 

 

$

7

 

 

$

 

 

$

425

 

Capital expenditures, including acquisitions

 

$

463

 

 

$

76

 

 

$

218

 

 

$

 

 

$

757

 

Three Months Ended June 30, 2016:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Revenues from external customers

 

$

1,365

 

 

$

266

 

 

$

857

 

 

$

 

 

$

2,488

 

Intersegment revenues

 

$

 

 

$

 

 

$

176

 

 

$

(176

)

 

$

 

Depreciation, depletion and amortization

 

$

256

 

 

$

103

 

 

$

125

 

 

$

 

 

$

484

 

Interest expense

 

$

108

 

 

$

33

 

 

$

47

 

 

$

(23

)

 

$

165

 

Asset impairments

 

$

885

 

 

$

612

 

 

$

 

 

$

 

 

$

1,497

 

Restructuring and transaction costs

 

$

19

 

 

$

4

 

 

$

1

 

 

$

 

 

$

24

 

Loss before income taxes

 

$

(1,097

)

 

$

(647

)

 

$

(1

)

 

$

 

 

$

(1,745

)

Income tax benefit

 

$

(6

)

 

$

(174

)

 

$

(2

)

 

$

 

 

$

(182

)

Net earnings (loss)

 

$

(1,091

)

 

$

(473

)

 

$

1

 

 

$

 

 

$

(1,563

)

Net earnings attributable to noncontrolling interests

 

$

1

 

 

$

 

 

$

6

 

 

$

 

 

$

7

 

Net loss attributable to Devon

 

$

(1,092

)

 

$

(473

)

 

$

(5

)

 

$

 

 

$

(1,570

)

Capital expenditures, including acquisitions

 

$

284

 

 

$

29

 

 

$

139

 

 

$

 

 

$

452

 

Six Months Ended June 30, 2017:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Revenues from external customers

 

$

3,972

 

 

$

593

 

 

$

2,245

 

 

$

 

 

$

6,810

 

Intersegment revenues

 

$

 

 

$

 

 

$

341

 

 

$

(341

)

 

$

 

Depreciation, depletion and amortization

 

$

361

 

 

$

136

 

 

$

265

 

 

$

 

 

$

762

 

Interest expense

 

$

161

 

 

$

31

 

 

$

84

 

 

$

(27

)

 

$

249

 

Asset impairments

 

$

 

 

$

 

 

$

7

 

 

$

 

 

$

7

 

Earnings before income taxes

 

$

966

 

 

$

41

 

 

$

49

 

 

$

 

 

$

1,056

 

Income tax expense

 

$

5

 

 

$

14

 

 

$

7

 

 

$

 

 

$

26

 

Net earnings

 

$

961

 

 

$

27

 

 

$

42

 

 

$

 

 

$

1,030

 

Net earnings attributable to noncontrolling interests

 

$

 

 

$

 

 

$

40

 

 

$

 

 

$

40

 

Net earnings attributable to Devon

 

$

961

 

 

$

27

 

 

$

2

 

 

$

 

 

$

990

 

Property and equipment, net

 

$

7,659

 

 

$

2,651

 

 

$

6,512

 

 

$

 

 

$

16,822

 

Total assets

 

$

13,096

 

 

$

3,505

 

 

$

10,265

 

 

$

(52

)

 

$

26,814

 

Capital expenditures, including acquisitions

 

$

900

 

 

$

172

 

 

$

466

 

 

$

 

 

$

1,538

 

Six Months Ended June 30, 2016:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Revenues from external customers

 

$

2,667

 

 

$

383

 

 

$

1,564

 

 

$

 

 

$

4,614

 

Intersegment revenues

 

$

 

 

$

 

 

$

359

 

 

$

(359

)

 

$

 

Depreciation, depletion and amortization

 

$

567

 

 

$

212

 

 

$

247

 

 

$

 

 

$

1,026

 

Interest expense

 

$

215

 

 

$

67

 

 

$

91

 

 

$

(43

)

 

$

330

 

Asset impairments

 

$

2,493

 

 

$

1,166

 

 

$

873

 

 

$

 

 

$

4,532

 

Restructuring and transaction costs

 

$

255

 

 

$

10

 

 

$

6

 

 

$

 

 

$

271

 

Loss before income taxes

 

$

(3,162

)

 

$

(1,396

)

 

$

(872

)

 

$

 

 

$

(5,430

)

Income tax benefit

 

$

(11

)

 

$

(382

)

 

$

(6

)

 

$

 

 

$

(399

)

Net loss

 

$

(3,151

)

 

$

(1,014

)

 

$

(866

)

 

$

 

 

$

(5,031

)

Net earnings (loss) attributable to noncontrolling interests

 

$

1

 

 

$

 

 

$

(406

)

 

$

 

 

$

(405

)

Net loss attributable to Devon

 

$

(3,152

)

 

$

(1,014

)

 

$

(460

)

 

$

 

 

$

(4,626

)

Property and equipment, net

 

$

7,823

 

 

$

2,832

 

 

$

6,160

 

 

$

 

 

$

16,815

 

Total assets

 

$

12,856

 

 

$

4,283

 

 

$

10,162

 

 

$

(57

)

 

$

27,244

 

Capital expenditures, including acquisitions

 

$

2,177

 

 

$

110

 

 

$

684

 

 

$

 

 

$

2,971

 

 

27

 


Table of Contents

 

 

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

The following discussion and analysis addresses material changes in our results of operations and capital resources and uses for the three-month and six-month periods ended June 30, 2017 compared to the three-month and six-month periods ended June 30, 2016 and in our financial condition and liquidity since December 31, 2016. For information regarding our critical accounting policies and estimates, see our 2016 Annual Report on Form 10-K under “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.”

Overview of 2017 Results

Key components of our financial performance are summarized below.

 

 

 

Three Months Ended June 30,

 

 

Six Months Ended June 30, (3)

 

 

 

2017

 

 

2016

 

 

Change

 

 

2017

 

 

2016

 

 

Change

 

 

 

(Millions, except per share amounts)

 

Net earnings (loss) attributable to Devon

 

$

425

 

 

$

(1,570

)

 

 

N/M

 

 

$

990

 

 

$

(4,626

)

 

 

N/M

 

Net earnings (loss) per diluted share attributable to Devon

 

$

0.80

 

 

$

(3.04

)

 

 

N/M

 

 

$

1.87

 

 

$

(9.33

)

 

 

N/M

 

Core earnings (loss) attributable to Devon (1)

 

$

177

 

 

$

33

 

 

 

N/M

 

 

$

394

 

 

$

(216

)

 

 

N/M

 

Core earnings (loss) per diluted share attributable to Devon (1)

 

$

0.34

 

 

$

0.06

 

 

 

N/M

 

 

$

0.75

 

 

$

(0.44

)

 

 

N/M

 

Retained production (MBoe/d)

 

 

536

 

 

 

574

 

 

 

- 7

%

 

 

550

 

 

 

592

 

 

 

- 7

%

Total production (MBoe/d)

 

 

536

 

 

 

644

 

 

 

- 17

%

 

 

550

 

 

 

665

 

 

 

- 17

%

Realized price per Boe (2)

 

$

24.72

 

 

$

18.50

 

 

 

+34

%

 

$

25.28

 

 

$

15.78

 

 

 

+60

%

Operating cash flow

 

$

810

 

 

$

345

 

 

 

+135

%

 

$

1,644

 

 

$

510

 

 

 

+222

%

Capital expenditures, including acquisitions

 

$

757

 

 

$

452

 

 

 

+67

%

 

$

1,538

 

 

$

2,971

 

 

 

- 48

%

Shareholder and noncontrolling interests distributions

 

$

115

 

 

$

107

 

 

 

+7

%

 

$

228

 

 

$

305

 

 

 

- 25

%

Cash and cash equivalents

 

 

 

 

 

 

 

 

 

 

 

 

 

$

2,369

 

 

$

1,723

 

 

 

+37

%

Total debt

 

 

 

 

 

 

 

 

 

 

 

 

 

$

10,558

 

 

$

12,707

 

 

 

- 17

%

 

(1)

Core earnings (loss) and core earnings (loss) per diluted share attributable to Devon are financial measures not prepared in accordance with GAAP. For a description of core earnings (loss) and core earnings (loss) per diluted share attributable to Devon, as well as reconciliations to the comparable GAAP measures, see “Non-GAAP Measures” in this Item 2.

(2)

Excludes any impact of oil, gas and NGL derivatives.

(3)

Except for balance sheet amounts, which are presented as of June 30.

 

During the first six months of 2017, Devon generated solid operating results with its three-fold strategy of operating in North America’s very best resource plays, delivering superior execution and maintaining a high degree of financial strength. Led by our development in the STACK, Delaware and Eagle Ford, we continued to improve our 90-day initial production rates. With investments in proprietary data tools, predictive analytics and artificial intelligence, we are delivering industry-leading, initial-rate well productivity performance and improving the performance of our established wells. Even though our 2017 production volumes have declined from 2016 due to reduced capital investment, we estimate our highest-margin U.S. oil production from retained assets will exit 2017 at a rate 18-23% higher than year-end 2016. This production growth is driven by our improved well productivity, along with increased drilling activity, and will build operational momentum into 2018.

 

Besides improving our upstream capital efficiency, we continued our focus on managing and reducing costs. With creative supply chain sourcing strategies, improved efficiency and lower debt levels, our aggregate LOE, gross G&A and financing costs declined $190 million, or 12%, during the first six months of 2017.

 

Compared to 2016, commodity prices increased significantly and were the primary driver for improvements in Devon’s operating margins, earnings and cash flow during the first six months of 2017. We exited the second quarter of 2017 with liquidity comprised of $2.4 billion of cash and $3 billion of available credit under our debt facility. We have no significant debt maturities until 2021. At June 30, 2017, we also had approximately 55% of our remaining 2017 forecasted oil production hedged at an average floor price of $50/Bbl and approximately 55% of our remaining 2017 forecasted natural gas production hedged at an average floor price of $3.10/MMBtu. We are building our 2018 hedge positions at similar prices.

 

We expect to further enhance our financial strength with our recently announced $1 billion asset divestiture program. The planned divestitures consist of 35,000 Boe/d of production from select non-core leasehold within the Barnett Shale and the Eagle

28


Table of Contents

Ford, along with other minor properties. Subsequent to June 30, 2017, we announced the $205 million sale of our non-core Eagle Ford assets in Lavaca County. Combined with other minor asset sales, we have now sold $340 million of assets under this program.  

 

Looking ahead, Devon has four priorities in the current environment as we execute on our strategy. We will continue to build and maintain momentum in the STACK and Delaware. We intend to organically fund our capital programs. We will execute on the remainder of our asset divestiture program. Finally, we expect to further improve our investment-grade financial strength.

 

 

29


Table of Contents

Results of Operations

Oil, Gas and NGL Production

 

 

Three Months Ended June 30,

 

 

Six Months Ended June 30,

 

 

 

2017

 

 

2016

 

 

Change

 

 

2017

 

 

2016

 

 

Change

 

Oil (MBbls/d)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Barnett Shale

 

 

1

 

 

 

1

 

 

 

- 36

%

 

 

1

 

 

 

1

 

 

 

- 25

%

Delaware Basin

 

 

30

 

 

 

36

 

 

 

- 14

%

 

 

30

 

 

 

37

 

 

 

- 18

%

Eagle Ford

 

 

36

 

 

 

41

 

 

 

- 12

%

 

 

42

 

 

 

50

 

 

 

- 16

%

Heavy Oil

 

 

17

 

 

 

22

 

 

 

- 22

%

 

 

18

 

 

 

24

 

 

 

- 25

%

Rockies Oil

 

 

13

 

 

 

15

 

 

 

- 9

%

 

 

13

 

 

 

16

 

 

 

- 15

%

STACK

 

 

25

 

 

 

19

 

 

 

+33

%

 

 

23

 

 

 

17

 

 

 

+35

%

Other

 

 

11

 

 

 

11

 

 

 

- 1

%

 

 

10

 

 

 

11

 

 

 

- 3

%

Retained assets

 

 

133

 

 

 

145

 

 

 

- 8

%

 

 

137

 

 

 

156

 

 

 

- 12

%

Divested assets

 

 

 

 

 

15

 

 

N/M

 

 

 

 

 

 

16

 

 

N/M

 

Total

 

 

133

 

 

 

160

 

 

 

- 17

%

 

 

137

 

 

 

172

 

 

 

- 20

%

Bitumen (MBbls/d)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Heavy Oil

 

 

105

 

 

 

99

 

 

 

+6

%

 

 

112

 

 

 

100

 

 

 

+12

%

Gas (MMcf/d)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Barnett Shale

 

 

675

 

 

 

757

 

 

 

- 11

%

 

 

679

 

 

 

763

 

 

 

- 11

%

Delaware Basin

 

 

96

 

 

 

99

 

 

 

- 3

%

 

 

92

 

 

 

91

 

 

 

+1

%

Eagle Ford

 

 

96

 

 

 

103

 

 

 

- 8

%

 

 

107

 

 

 

124

 

 

 

- 14

%

Heavy Oil

 

 

14

 

 

 

28

 

 

 

- 51

%

 

 

18

 

 

 

22

 

 

 

- 15

%

Rockies Oil

 

 

17

 

 

 

31

 

 

 

- 45

%

 

 

16

 

 

 

31

 

 

 

- 49

%

STACK

 

 

298

 

 

 

289

 

 

 

+3

%

 

 

293

 

 

 

298

 

 

 

- 2

%

Other

 

 

12

 

 

 

14

 

 

 

- 9

%

 

 

13

 

 

 

15

 

 

 

- 16

%

Retained assets

 

 

1,208

 

 

 

1,321

 

 

 

- 9

%

 

 

1,218

 

 

 

1,344

 

 

 

- 9

%

Divested assets

 

 

 

 

 

206

 

 

N/M

 

 

 

 

 

 

210

 

 

N/M

 

Total

 

 

1,208

 

 

 

1,527

 

 

 

- 21

%

 

 

1,218

 

 

 

1,554

 

 

 

- 22

%

NGLs (MBbls/d)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Barnett Shale

 

 

42

 

 

 

46

 

 

 

- 8

%

 

 

43

 

 

 

46

 

 

 

- 7

%

Delaware Basin

 

 

10

 

 

 

13

 

 

 

- 26

%

 

 

10

 

 

 

12

 

 

 

- 22

%

Eagle Ford

 

 

11

 

 

 

17

 

 

 

- 36

%

 

 

13

 

 

 

21

 

 

 

- 36

%

Rockies Oil

 

 

1

 

 

 

1

 

 

 

+12

%

 

 

1

 

 

 

1

 

 

 

- 7

%

STACK

 

 

31

 

 

 

30

 

 

 

+2

%

 

 

28

 

 

 

30

 

 

 

- 5

%

Other

 

 

2

 

 

 

3

 

 

 

- 16

%

 

 

2

 

 

 

3

 

 

 

- 15

%

Retained assets

 

 

97

 

 

 

110

 

 

 

- 12

%

 

 

97

 

 

 

113

 

 

 

- 14

%

Divested assets

 

 

 

 

 

21

 

 

N/M

 

 

 

 

 

 

21

 

 

N/M

 

Total

 

 

97

 

 

 

131

 

 

 

- 26

%

 

 

97

 

 

 

134

 

 

 

- 27

%

Combined (MBoe/d)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Barnett Shale

 

 

155

 

 

 

173

 

 

 

- 10

%

 

 

157

 

 

 

174

 

 

 

- 10

%

Delaware Basin

 

 

56

 

 

 

65

 

 

 

- 14

%

 

 

55

 

 

 

64

 

 

 

- 14

%

Eagle Ford

 

 

63

 

 

 

76

 

 

 

- 16

%

 

 

73

 

 

 

91

 

 

 

- 20

%

Heavy Oil

 

 

124

 

 

 

126

 

 

 

- 1

%

 

 

133

 

 

 

127

 

 

 

+4

%

Rockies Oil

 

 

18

 

 

 

21

 

 

 

- 16

%

 

 

17

 

 

 

22

 

 

 

- 23

%

STACK

 

 

105

 

 

 

97

 

 

 

+9

%

 

 

100

 

 

 

97

 

 

 

+4

%

Other

 

 

15

 

 

 

16

 

 

 

- 11

%

 

 

15

 

 

 

17

 

 

 

- 13

%

Retained assets

 

 

536

 

 

 

574

 

 

 

- 7

%

 

 

550

 

 

 

592

 

 

 

- 7

%

Divested assets

 

 

 

 

 

70

 

 

N/M

 

 

 

 

 

 

73

 

 

N/M

 

Total

 

 

536

 

 

 

644

 

 

 

- 17

%

 

 

550

 

 

 

665

 

 

 

- 17

%

 

30


Table of Contents

Oil, Gas and NGL Pricing

 

 

 

Three Months Ended June 30,

 

 

Six Months Ended June 30,

 

 

 

2017 (1)

 

 

2016 (1)

 

 

Change

 

 

2017 (1)

 

 

2016 (1)

 

 

Change

 

Oil (per Bbl)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

U.S.

 

$

46.65

 

 

$

41.56

 

 

 

+12

%

 

$

48.18

 

 

$

34.70

 

 

 

+39

%

Canada

 

$

32.44

 

 

$

27.62

 

 

 

+17

%

 

$

31.58

 

 

$

19.86

 

 

 

+59

%

Total

 

$

44.83

 

 

$

39.64

 

 

 

+13

%

 

$

46.04

 

 

$

32.64

 

 

 

+41

%

Bitumen (per Bbl)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Canada

 

$

28.49

 

 

$

21.40

 

 

 

+33

%

 

$

26.96

 

 

$

14.73

 

 

 

+83

%

Gas (per Mcf)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

U.S.

 

$

2.50

 

 

$

1.40

 

 

 

+78

%

 

$

2.59

 

 

$

1.47

 

 

 

+77

%

NGLs (per Bbl)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

U.S.

 

$

13.26

 

 

$

10.14

 

 

 

+31

%

 

$

14.36

 

 

$

8.46

 

 

 

+70

%

Combined (per Boe)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

U.S.

 

$

23.58

 

 

$

17.68

 

 

 

+33

%

 

$

24.72

 

 

$

15.89

 

 

 

+56

%

Canada

 

$

28.50

 

 

$

21.85

 

 

 

+30

%

 

$

27.03

 

 

$

15.33

 

 

 

+76

%

Total

 

$

24.72

 

 

$

18.50

 

 

 

+34

%

 

$

25.28

 

 

$

15.78

 

 

 

+60

%

 

 

(1)

Prices presented exclude any effects of oil, gas and NGL derivatives.

Commodity Sales

The volume and price changes in the tables above caused the following changes to our commodity sales between the three and six months ended June 30, 2017 and 2016.

 

 

Three Months Ended June 30,

 

 

 

Oil

 

 

Bitumen

 

 

Gas

 

 

NGLs

 

 

Total

 

 

 

(Millions)

 

2016 sales

 

$

575

 

 

$

193

 

 

$

195

 

 

$

122

 

 

$

1,085

 

Change due to volumes

 

 

(95

)

 

 

11

 

 

 

(41

)

 

 

(33

)

 

 

(158

)

Change due to prices

 

 

63

 

 

 

68

 

 

 

121

 

 

 

27

 

 

 

279

 

2017 sales

 

$

543

 

 

$

272

 

 

$

275

 

 

$

116

 

 

$

1,206

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Six Months Ended June 30,

 

 

 

Oil

 

 

Bitumen

 

 

Gas

 

 

NGLs

 

 

Total

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

(Millions)

 

2016 sales

 

$

1,020

 

 

$

268

 

 

$

415

 

 

$

207

 

 

$

1,910

 

Change due to volumes

 

 

(209

)

 

 

30

 

 

 

(92

)

 

 

(57

)

 

 

(328

)

Change due to prices

 

 

333

 

 

 

248

 

 

 

248

 

 

 

104

 

 

 

933

 

2017 sales

 

$

1,144

 

 

$

546

 

 

$

571

 

 

$

254

 

 

$

2,515

 

 

Commodity sales increased in the second quarter and the first six months of 2017 due to significant price increases for all commodities. The increase in oil and bitumen sales resulted from a higher average WTI crude oil index price. Additionally, our bitumen sales benefited from tighter bitumen and heavy oil differentials. The increases in gas and NGL sales were due to higher North American regional index prices upon which our gas sales are based and higher NGL prices at the Mont Belvieu, Texas hub.  

 

The increase in sales due to the favorable movement in commodity prices was partially offset by a decline in production volumes. In 2016, we significantly reduced our drilling and completion capital programs in response to depressed commodity prices. Consequently, our U.S. production volumes steadily declined throughout 2016. Asset divestitures also caused our volumes to decline significantly in the third and fourth quarters of 2016.

31


Table of Contents

Oil, Gas and NGL Derivatives

A summary of our open commodity derivative positions is included in Note 3 to the financial statements included in “Part I. Financial Information – Item 1. Financial Statements” of this report. The following tables provide financial information associated with our oil, gas and NGL hedges. The first table presents the cash settlements and fair value gains and losses recognized as components of our revenues. The subsequent tables present our oil, gas and NGL prices with, and without, the effects of the cash settlements. The prices do not include the effects of fair value gains and losses.

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended June 30,

 

 

Six Months Ended June 30,

 

 

 

2017

 

 

2016

 

 

2017

 

 

2016

 

 

 

(Millions)

 

Cash settlements:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Oil derivatives

 

$

6

 

 

$

(61

)

 

$

18

 

 

$

(61

)

Gas derivatives

 

 

5

 

 

 

32

 

 

 

1

 

 

 

51

 

NGL derivatives

 

 

 

 

 

(2

)

 

 

 

 

 

(2

)

Total cash settlements

 

 

11

 

 

 

(31

)

 

 

19

 

 

 

(12

)

Gains (losses) on fair value changes:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Oil derivatives

 

 

85

 

 

 

(28

)

 

 

229

 

 

 

(30

)

Gas derivatives

 

 

30

 

 

 

(77

)

 

 

108

 

 

 

(61

)

NGL derivatives

 

 

 

 

 

(6

)

 

 

2

 

 

 

(6

)

Total gains (losses) on fair value changes

 

 

115

 

 

 

(111

)

 

 

339

 

 

 

(97

)

Oil, gas and NGL derivatives

 

$

126

 

 

$

(142

)

 

$

358

 

 

$

(109

)

 

 

 

Three Months Ended June 30, 2017

 

 

 

Oil

 

 

Bitumen

 

 

Gas

 

 

NGLs

 

 

Boe

 

 

 

(Per Bbl)

 

 

(Per Bbl)

 

 

(Per Mcf)

 

 

(Per Bbl)

 

 

(Per Boe)

 

Realized price without hedges

 

$

44.83

 

 

$

28.49

 

 

$

2.50

 

 

$

13.26

 

 

$

24.72

 

Cash settlements of hedges

 

 

0.52

 

 

 

 

 

 

0.04

 

 

 

(0.03

)

 

 

0.22

 

Realized price, including cash settlements

 

$

45.35

 

 

$

28.49

 

 

$

2.54

 

 

$

13.23

 

 

$

24.94

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended June 30, 2016

 

 

 

Oil

 

 

Bitumen

 

 

Gas

 

 

NGLs

 

 

Boe

 

 

 

(Per Bbl)

 

 

(Per Bbl)

 

 

(Per Mcf)

 

 

(Per Bbl)

 

 

(Per Boe)

 

Realized price without hedges

 

$

39.64

 

 

$

21.40

 

 

$

1.40

 

 

$

10.14

 

 

$

18.50

 

Cash settlements of hedges

 

 

(4.17

)

 

 

 

 

 

0.24

 

 

 

(0.25

)

 

 

(0.53

)

Realized price, including cash settlements

 

$

35.47

 

 

$

21.40

 

 

$

1.64

 

 

$

9.89

 

 

$

17.97

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Six Months Ended June 30, 2017

 

 

 

Oil

 

 

Bitumen

 

 

Gas

 

 

NGLs

 

 

Boe

 

 

 

(Per Bbl)

 

 

(Per Bbl)

 

 

(Per Mcf)

 

 

(Per Bbl)

 

 

(Per Boe)

 

Realized price without hedges

 

$

46.04

 

 

$

26.96

 

 

$

2.59

 

 

$

14.36

 

 

$

25.28

 

Cash settlements of hedges

 

 

0.72

 

 

 

 

 

 

 

 

 

(0.02

)

 

 

0.19

 

Realized price, including cash settlements

 

$

46.76

 

 

$

26.96

 

 

$

2.59

 

 

$

14.34

 

 

$

25.47

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Six Months Ended June 30, 2016

 

 

 

Oil

 

 

Bitumen

 

 

Gas

 

 

NGLs

 

 

Boe

 

 

 

(Per Bbl)

 

 

(Per Bbl)

 

 

(Per Mcf)

 

 

(Per Bbl)

 

 

(Per Boe)

 

Realized price without hedges

 

$

32.64

 

 

$

14.73

 

 

$

1.47

 

 

$

8.46

 

 

$

15.78

 

Cash settlements of hedges

 

 

(1.94

)

 

 

 

 

 

0.18

 

 

 

(0.13

)

 

 

(0.10

)

Realized price, including cash settlements

 

$

30.70

 

 

$

14.73

 

 

$

1.65

 

 

$

8.33

 

 

$

15.68

 

 

Cash settlements as presented in the tables above represent realized gains or losses related to various commodity derivatives. In addition to cash settlements, we also recognize fair value changes on our oil, gas and NGL derivative instruments in each reporting period. The changes in fair value resulted from new positions and settlements that occurred during each period, as well as the

32


Table of Contents

relationships between contract prices and the associated forward curves. Including the cash settlements discussed above, our oil, gas and NGL derivatives generated net gains in the second quarter and first six months of 2017. Including the cash settlements discussed above, our oil, gas and NGL derivatives incurred net losses in the second quarter and first six months of 2016.

Marketing and Midstream Revenues and Operating Expenses

 

 

 

Three Months Ended June 30,

 

 

Six Months Ended June 30,

 

 

 

2017

 

 

2016

 

 

Change

 

 

2017

 

 

2016

 

 

Change

 

 

 

(Millions)

 

Operating revenues

 

$

1,927

 

 

$

1,545

 

 

 

+25

%

 

$

3,937

 

 

$

2,813

 

 

 

+40

%

Product purchases

 

 

(1,611

)

 

 

(1,248

)

 

 

+29

%

 

 

(3,322

)

 

 

(2,227

)

 

 

+49

%

Operations and maintenance expenses

 

 

(92

)

 

 

(90

)

 

 

+2

%

 

 

(184

)

 

 

(177

)

 

 

+4

%

Operating profit

 

$

224

 

 

$

207

 

 

 

+8

%

 

$

431

 

 

$

409

 

 

 

+5

%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Devon loss

 

$

(16

)

 

$

(4

)

 

 

+300

%

 

$

(36

)

 

$

(19

)

 

 

+89

%

EnLink profit

 

 

240

 

 

 

211

 

 

 

+14

%

 

 

467

 

 

 

428

 

 

 

+9

%

Total profit

 

$

224

 

 

$

207

 

 

 

+8

%

 

$

431

 

 

$

409

 

 

 

+5

%

 

 

The overall increase in marketing and midstream margin during the second quarter and the first six months of 2017 was primarily due to an increase in EnLink’s throughput volumes related to gas processing and transmission activities, offset by a decline in margins on Devon’s downstream marketing commitments. Devon is actively engaged in optimization activities to improve margins to help offset the costs of downstream commitments; however, we expect those commitments to negatively impact our margins throughout 2017.

Lease Operating Expenses

 

 

 

Three Months Ended June 30,

 

 

Six Months Ended June 30,

 

 

 

2017

 

 

2016

 

 

Change

 

 

2017

 

 

2016

 

 

Change

 

 

 

(Millions, except per Boe amounts)

 

LOE:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

U.S.

 

$

253

 

 

$

295

 

 

 

- 14

%

 

$

505

 

 

$

638

 

 

 

- 21

%

Canada

 

 

146

 

 

 

121

 

 

 

+20

%

 

 

280

 

 

 

222

 

 

 

+26

%

Total

 

$

399

 

 

$

416

 

 

 

- 4

%

 

$

785

 

 

$

860

 

 

 

- 9

%

LOE per Boe:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

U.S.

 

$

6.75

 

 

$

6.25

 

 

 

+8

%

 

$

6.70

 

 

$

6.52

 

 

 

+3

%

Canada

 

$

12.92

 

 

$

10.58

 

 

 

+22

%

 

$

11.64

 

 

$

9.58

 

 

 

+22

%

Total

 

$

8.18

 

 

$

7.09

 

 

 

+15

%

 

$

7.90

 

 

$

7.11

 

 

 

+11

%

 

Our absolute LOE decreased during the second quarter and the first six months of 2017 primarily due to our non-core U.S. property divestitures during 2016 and continued well optimization and cost reduction initiatives. These initiatives have been primarily focused on reducing costs associated with water disposal, power and fuel, compression and workovers. These cost savings were partially offset by Access Pipeline transportation tolls of $29 million and $60 million during the second quarter and first six months of 2017, respectively, which commenced in the fourth quarter of 2016 subsequent to the sale of our interest in the pipeline. The Access Pipeline transportation tolls were the primary driver in the increase in Canada LOE per BOE compared to the second quarter and the first six months of 2016.

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General and Administrative Expenses

 

 

 

Three Months Ended June 30,

 

 

Six Months Ended June 30,

 

 

 

2017

 

 

2016

 

 

Change

 

 

2017

 

 

2016

 

 

Change

 

 

 

(Millions, except per Boe amounts)

 

Gross G&A

 

$

207

 

 

$

196

 

 

 

+6

%

 

$

427

 

 

$

458

 

 

 

- 7

%

Capitalized G&A

 

 

(56

)

 

 

(56

)

 

 

+0

%

 

 

(115

)

 

 

(129

)

 

 

- 11

%

Reimbursed G&A

 

 

(18

)

 

 

(22

)

 

 

- 19

%

 

 

(34

)

 

 

(47

)

 

 

- 28

%

Devon Net G&A

 

 

133

 

 

 

118

 

 

 

+13

%

 

 

278

 

 

 

282

 

 

 

- 1

%

EnLink Net G&A

 

 

31

 

 

 

29

 

 

 

+6

%

 

 

67

 

 

 

59

 

 

 

+12

%

Net G&A

 

$

164

 

 

$

147

 

 

 

+12

%

 

$

345

 

 

$

341

 

 

 

+1

%

 

Gross G&A increased during the second quarter of 2017 due to employee severance costs and decreased the first six months of 2017 largely due to lower Devon employee costs resulting from the 2016 workforce reductions and other cost reduction initiatives. Reimbursed G&A decreased primarily due to the divestitures of operated properties in 2016. EnLink net G&A increased during the second quarter and for the first six months of 2017 primarily due to higher employee compensation costs.

Production and Property Taxes

 

 

 

Three Months Ended June 30,

 

 

Six Months Ended June 30,

 

 

 

2017

 

 

2016

 

 

Change

 

 

2017

 

 

2016

 

 

Change

 

 

 

(Millions)

 

Production taxes

 

$

38

 

 

$

38

 

 

 

+2

%

 

$

91

 

 

$

71

 

 

 

+28

%

Property and other taxes

 

 

21

 

 

 

26

 

 

 

- 20

%

 

 

42

 

 

 

60

 

 

 

- 30

%

Devon production and property taxes

 

 

59

 

 

 

64

 

 

 

- 7

%

 

 

133

 

 

 

131

 

 

 

+2

%

EnLink property taxes

 

 

12

 

 

 

11

 

 

 

+9

%

 

 

23

 

 

 

22

 

 

 

+5

%

Production and property taxes

 

$

71

 

 

$

75

 

 

 

- 6

%

 

$

156

 

 

$

153

 

 

 

+2

%

Percentage of oil, gas and NGL sales:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Production taxes

 

 

3.1

%

 

 

3.5

%

 

 

- 9

%

 

 

3.6

%

 

 

3.7

%

 

 

- 3

%

Property and other taxes

 

 

2.7

%

 

 

3.4

%

 

 

- 22

%

 

 

2.6

%

 

 

4.3

%

 

 

- 40

%

Total

 

 

5.8

%

 

 

6.9

%

 

 

- 16

%

 

 

6.2

%

 

 

8.0

%

 

 

- 22

%

 

Production taxes increased during each period in 2017 on an absolute dollar basis primarily due to an increase in our U.S. revenues, on which the majority of our production taxes are assessed. Property and other taxes decreased in each period of 2017 primarily as a result of lower property value assessments from the local taxing authorities across our key operating areas and as a result of our non-core oil and gas property divestitures during 2016. Property taxes do not always change in direct correlation with the change in oil, gas and NGL sales and are generally determined based on the valuation of the underlying assets.

Depreciation, Depletion and Amortization

 

 

 

Three Months Ended June 30,

 

 

Six Months Ended June 30,

 

 

 

2017

 

 

2016

 

 

Change

 

 

2017

 

 

2016

 

 

Change

 

 

 

(Millions, except per Boe amounts)

 

DD&A:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Oil and gas properties

 

$

218

 

 

$

313

 

 

 

- 30

%

 

$

443

 

 

$

691

 

 

 

- 36

%

Other assets

 

 

26

 

 

 

46

 

 

 

- 45

%

 

 

54

 

 

 

88

 

 

 

- 38

%

Devon DD&A

 

 

244

 

 

 

359

 

 

 

- 32

%

 

 

497

 

 

 

779

 

 

 

- 36

%

EnLink DD&A

 

 

137

 

 

 

125

 

 

 

+9

%

 

 

265

 

 

 

247

 

 

 

+7

%

Total DD&A

 

$

381

 

 

$

484

 

 

 

- 21

%

 

$

762

 

 

$

1,026

 

 

 

- 26

%

DD&A per Boe:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Oil and gas properties

 

$

4.45

 

 

$

5.33

 

 

 

- 16

%

 

$

4.45

 

 

$

5.71

 

 

 

- 22

%

 

DD&A from our oil and gas properties decreased in the second quarter and the first six months of 2017 largely due to lower DD&A rates, resulting from the oil and gas asset impairments and non-core U.S. divestures in 2016. DD&A from our other assets

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decreased due to the divestiture of Access Pipeline in the fourth quarter of 2016. EnLink’s DD&A increased primarily due to acquisitions made during 2016.

Asset Impairments

During the second quarter and the first six months of 2016, we recognized asset impairments totaling $1.5 billion and $4.5 billion, respectively. For further discussion, see Note 5 in “Part I. Financial Information – Item 1. Financial Statements” of this report.

Restructuring and Transaction Costs

During the first six months of 2016, we recognized restructuring costs of $256 million as a result of a reduction in workforce driven by our cost reduction initiatives and divestiture of non-core properties.

During the first six months of 2016, we recognized transaction costs of $15 million, primarily associated with the closing of the acquisitions discussed in Note 2 in “Part I. Financial Information – Item 1. Financial Statements” of this report.

Net Financing Costs

 

 

 

Three Months Ended June 30,

 

 

Six Months Ended June 30,

 

 

 

2017

 

 

2016

 

 

Change

 

 

2017

 

 

2016

 

 

Change

 

 

 

(Millions)

 

Devon net financing costs:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Interest based on debt outstanding

 

$

98

 

 

$

128

 

 

 

- 23

%

 

$

195

 

 

$

256

 

 

 

- 24

%

Capitalized interest

 

 

(17

)

 

 

(17

)

 

 

-1

%

 

 

(34

)

 

 

(31

)

 

 

+11

%

Other

 

 

(4

)

 

 

5

 

 

 

-168

%

 

 

(2

)

 

 

11

 

 

 

- 114

%

Total Devon net financing costs

 

 

77

 

 

 

116

 

 

 

- 34

%

 

 

159

 

 

 

236

 

 

 

- 33

%

EnLink net financing costs:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Interest based on debt outstanding

 

 

42

 

 

 

35

 

 

 

+20

%

 

 

82

 

 

 

68

 

 

 

+21

%

Interest accretion on deferred installment payment

 

 

6

 

 

 

14

 

 

 

-57

%

 

 

13

 

 

 

26

 

 

 

- 50

%

Other

 

 

(9

)

 

 

(2

)

 

 

+350

%

 

 

(11

)

 

 

(3

)

 

 

+267

%

Total EnLink net financing costs

 

 

39

 

 

 

47

 

 

 

- 17

%

 

 

84

 

 

 

91

 

 

 

- 8

%

Total net financing costs

 

$

116

 

 

$

163

 

 

 

- 29

%

 

$

243

 

 

$

327

 

 

 

- 26

%

 

Devon’s net financing costs decreased during the second quarter and the first six months of 2017 primarily due to the repayment of $2.5 billion in borrowings, including scheduled maturities and early retirements funded with asset divestiture proceeds. EnLink’s net financing costs decreased during the second quarter and first six months of 2017 due to a gain on extinguishment of debt as disclosed in Note 14 in “Part I. Financial Information – Item 1. Financial Statements” of this report.

Income Taxes

 

 

 

Three Months Ended June 30,

 

 

Six Months Ended June 30,

 

 

 

2017

 

 

2016

 

 

2017

 

 

2016

 

 

 

(Millions)

 

Current income tax expense (benefit)

 

$

12

 

 

$

(3

)

 

$

32

 

 

$

(13

)

Deferred income tax benefit

 

 

(5

)

 

 

(179

)

 

 

(6

)

 

 

(386

)

Total income tax expense (benefit)

 

$

7

 

 

$

(182

)

 

$

26

 

 

$

(399

)

Effective income tax rate

 

 

2

%

 

 

10

%

 

 

2

%

 

 

7

%

 

We continue to expect low current income tax rates in the U.S. segment based on our continuing net operating loss position. For further discussion on income taxes, see Note 7 in “Part I. Financial Information – Item 1. Financial Statements” of this report.

 

 

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Table of Contents

Capital Resources, Uses and Liquidity

Sources and Uses of Cash

The following table presents the major changes in cash and cash equivalents for the six months ended June 30, 2017 and 2016.

 

 

 

Devon

 

 

EnLink

 

 

Consolidated

 

 

 

2017

 

 

2016

 

 

2017

 

 

2016

 

 

2017

 

 

2016

 

 

 

(Millions)

 

Operating cash flow

 

$

1,315

 

 

$

206

 

 

$

329

 

 

$

304

 

 

$

1,644

 

 

$

510

 

Issuance of common stock

 

 

 

 

 

1,469

 

 

 

 

 

 

 

 

 

 

 

 

1,469

 

Proceeds from sale of investment

 

 

 

 

 

 

 

 

190

 

 

 

 

 

 

190

 

 

 

 

Divestitures of property and equipment

 

 

113

 

 

 

208

 

 

 

1

 

 

 

1

 

 

 

114

 

 

 

209

 

Capital expenditures

 

 

(996

)

 

 

(950

)

 

 

(472

)

 

 

(288

)

 

 

(1,468

)

 

 

(1,238

)

Acquisitions of property, equipment and businesses

 

 

(33

)

 

 

(847

)

 

 

 

 

 

(791

)

 

 

(33

)

 

 

(1,638

)

Debt activity, net

 

 

 

 

 

(627

)

 

 

410

 

 

 

298

 

 

 

410

 

 

 

(329

)

Payment of installment payable

 

 

 

 

 

 

 

 

(250

)

 

 

 

 

 

(250

)

 

 

 

Shareholder and noncontrolling interests distributions

 

 

(65

)

 

 

(158

)

 

 

(163

)

 

 

(147

)

 

 

(228

)

 

 

(305

)

EnLink and General Partner distributions

 

 

133

 

 

 

133

 

 

 

(133

)

 

 

(133

)

 

 

 

 

 

 

Issuance of subsidiary units

 

 

 

 

 

 

 

 

72

 

 

 

776

 

 

 

72

 

 

 

776

 

Effect of exchange rate and other

 

 

(57

)

 

 

(13

)

 

 

16

 

 

 

(28

)

 

 

(41

)

 

 

(41

)

Net change in cash and cash equivalents

 

$

410

 

 

$

(579

)

 

$

 

 

$

(8

)

 

$

410

 

 

$

(587

)

Cash and cash equivalents at end of period

 

$

2,358

 

 

$

1,713

 

 

$

11

 

 

$

10

 

 

$

2,369

 

 

$

1,723

 

 

Operating Cash Flow

Net cash provided by operating activities increased approximately 220% primarily due to significantly higher commodity prices and lower operating costs as compared to the first six months of 2016.

Our consolidated operating cash flow funded 100% of our capital expenditures during the first six months of 2017. In 2016, leveraging our liquidity, we also used cash balances and proceeds from our common stock offering and non-core asset divestitures to fund our acquisitions and capital expenditures.

Issuance of Common Stock

In February 2016, we issued 79 million shares of our common stock to the public, inclusive of 10 million shares sold as part of the underwriters’ option. Net proceeds from the offering were approximately $1.5 billion.

Proceeds from Sale of Investment

During the first quarter of 2017, EnLink divested its ownership interest in Howard Energy Partners for approximately $190 million. Proceeds were primarily used to pay a portion of the $250 million installment payment related to EnLink’s 2016 acquisition further discussed in Note 2 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

Divestitures of Property and Equipment

During the first six months of 2017, Devon sold non-core U.S. assets for approximately $100 million. In June 2016, we sold our non-core Mississippian assets for approximately $200 million. For further discussion, see Note 2 in “Part 1. Financial Information – Item 1. Financial Statements” in this report.

 

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Table of Contents

Capital Expenditures and Acquisitions of Property, Equipment and Businesses

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

 

 

 

Six Months Ended June 30,

 

 

 

2017

 

 

2016

 

 

 

(Millions)

 

Oil and gas

 

$

962

 

 

$

932

 

Corporate and other

 

 

34

 

 

 

18

 

Devon capital expenditures

 

 

996

 

 

 

950

 

EnLink capital expenditures

 

 

472

 

 

 

288

 

Total capital expenditures

 

$

1,468

 

 

$

1,238

 

Devon acquisitions

 

 

33

 

 

 

847

 

EnLink acquisitions

 

 

 

 

 

791

 

Total acquisitions

 

$

33

 

 

$

1,638

 

 

Capital expenditures consist of amounts related to our oil and gas exploration and development operations, midstream operations, other corporate activities and EnLink growth and maintenance activities. The vast majority of Devon’s capital expenditures are for the acquisition, drilling and development of oil and gas properties. Devon’s 2017 objectives are to concentrate capital spend in the STACK and Delaware Basin, while investing within cash flow and maintaining significant flexibility. Our capital investment program is driven by a disciplined allocation process focused on returns.

Capital expenditures for Devon’s and EnLink’s midstream operations are primarily for the construction and expansion of oil and gas gathering facilities and pipelines. Midstream capital expenditures are largely impacted by oil and gas development activities.

Acquisition capital for the first six months of 2016 primarily consisted of Devon’s acquisition of assets in the STACK play for approximately $1.5 billion and EnLink’s acquisition of Anadarko Basin gathering and processing midstream assets for $1.4 billion. Approximately $850 million and $800 million, respectively, was paid in cash at the closings with the remainder funded with equity consideration and debt. For additional information, see Note 2 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

Debt Activity, Net

During the first six months of 2017, consolidated net debt borrowings increased $410 million. In May 2017, EnLink issued $500 million of 5.45% senior notes due in 2047 to repay outstanding borrowings under its revolving credit facility and for general partnership purposes. Additionally, in June 2017, EnLink redeemed its 7.125% senior unsecured notes due in 2022.

During the first six months of 2016, we reduced our debt by $329 million. The decrease was primarily due to reducing our commercial paper balances by $626 million and was partially offset by EnLink’s increased credit facility borrowings to fund acquisitions and growth capital expenditures.

Payment of Installment Payable

          During the first quarter of 2017, EnLink made the first installment payment related to its 2016 acquisition further discussed in Note 2 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

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Table of Contents

Shareholder and Noncontrolling Interests Distributions

The following table summarizes our common stock dividends during the first six months of 2017 and 2016. In the second quarter of 2016, we decreased our quarterly cash dividend rate to $0.06 per share.

 

 

Amounts

 

 

Rate

 

 

(Millions)

 

 

(Per Share)

 

Quarter Ended 2017:

 

 

 

 

 

 

 

First quarter 2017

$

32

 

 

$

0.06

 

Second quarter 2017

 

33

 

 

$

0.06

 

Total year-to-date

$

65

 

 

 

 

 

Quarter Ended 2016:

 

 

 

 

 

 

 

First quarter 2016

$

125

 

 

$

0.24

 

Second quarter 2016

 

33

 

 

$

0.06

 

Total year-to-date

$

158

 

 

 

 

 

 

EnLink and the General Partner distributed $163 million and $147 million to non-Devon unitholders during the first six months of 2017 and 2016, respectively.

EnLink and General Partner Distributions

Devon received $133 million in distributions from EnLink and the General Partner during the first six months of 2017 and 2016.

Issuance of Subsidiary Units

During the first six months of 2017, EnLink issued and sold 4 million common units through its “at the market” program and generated $72 million in net proceeds. Additionally, during the first six months of 2016, EnLink issued and sold 3 million common units for net proceeds of $52 million through its “at the market” program.

In January 2016, as part of its acquisition of Anadarko Basin gathering and processing midstream assets, EnLink issued 50 million preferred units in a private placement generating cash proceeds of approximately $725 million. General Partner common units were also issued as consideration in the transaction.

Liquidity

Our primary sources of capital and liquidity are our operating cash flow, asset divestiture proceeds and cash on hand. Additionally, we maintain a commercial paper program, supported by our revolving line of credit, which can be accessed as needed to supplement operating cash flow and cash balances. Available sources of capital and liquidity also include, among other things, debt and equity securities that can be issued pursuant to our shelf registration statement filed with the SEC, as well as the sale of a portion of our common units representing interests in our investment in EnLink and the General Partner. We estimate the combination of these sources of capital will continue to be adequate to fund our planned capital expenditures, future debt repayments and other contractual commitments as discussed in this section.

Operating Cash Flow

Our operating cash flow is sensitive to many variables, the most volatile of which are the prices of the oil, bitumen, gas and NGLs we produce and sell. Our consolidated operating cash flow increased approximately $1.1 billion in the first six months of 2017 compared to the first six months of 2016 largely due to increases in commodity prices. We expect operating cash flow to continue to be a key source of liquidity as we adjust our capital program to invest within our operating cash flow. Additionally, proceeds from non-core asset divestitures will provide additional liquidity as needed.

To mitigate some of the risk inherent in prices, we utilize various derivative financial instruments to protect a portion of our production against downside price risk. We target hedging approximately 50% of our production in a manner that systematically places hedges for several quarters in advance, allowing us to maintain a disciplined risk management program as it relates to commodity price volatility. We supplement the systematic hedging program with discretionary hedges that take advantage of

38


Table of Contents

favorable market conditions. For additional information on our derivative positions in place at June 30, 2017, see Note 3 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

Divestiture of Property and Equipment

          In May 2017, we announced a program to divest approximately $1 billion of non-core upstream assets, which includes select portions of the Barnett Shale focused primarily in and around Johnson County and other minor properties across the U.S. Devon has reached an agreement to sell our non-core Eagle Ford assets in Lavaca County for $205 million. The transaction is expected to close in the second half of 2017 and will bring our total divestiture proceeds to $340 million when combined with other minor asset sales. We expect to open the Barnett Shale data room to potential buyers in the third quarter of 2017.

Capital Expenditures

Excluding EnLink, our 2017 capital expenditures are expected to range from $2.2 billion to $2.6 billion, including $1.9 billion to $2.2 billion for our exploration and development capital program. Our capital expenditures excluding EnLink were $1.1 billion in the first six months of 2017, are forecasted to range from $0.6 million to $0.7 million in the third quarter of 2017 and are forecasted to range from $0.5 million to $0.8 million in the fourth quarter of 2017.

Credit Availability

We have a $3.0 billion Senior Credit Facility. As of June 30, 2017, we had approximately $2.9 billion available under this facility, net of $58 million in outstanding letters of credit, and were in compliance with the facility’s financial covenant. This credit facility supports our $3.0 billion of short-term credit under our commercial paper program. At June 30, 2017, there were no borrowings under our commercial paper program.

EnLink Liquidity

EnLink has a $1.5 billion unsecured revolving credit facility. The General Partner has a $250 million secured revolving credit facility. As of June 30, 2017, there were $9 million in outstanding letters of credit and $166 million borrowed under the $1.5 billion credit facility and $65 million in outstanding borrowings under the $250 million credit facility. All of EnLink’s and the General Partner’s debt is non-recourse to Devon.

In January 2017, EnLink paid the first $250 million installment payment related to the 2016 Anadarko Basin gathering and processing midstream asset acquisition. The remaining $250 million installment payment is payable by January 2018.

Debt Ratings

We receive debt ratings from the major ratings agencies in the U.S. In determining our debt ratings, the agencies consider a number of qualitative and quantitative items including, but not limited to, commodity pricing levels, our liquidity, asset quality, reserve mix, debt levels, cost structure, planned asset sales and near-term and long-term production growth opportunities. Our credit rating from Standard and Poor’s Financial Services is BBB with a stable outlook. In March 2017, Fitch Ratings affirmed our BBB+ rating and revised our outlook to stable from negative. In April 2017, Moody’s Investor Service upgraded our credit rating from Ba2 to Ba1 with a stable outlook. Any rating downgrades may result in additional letters of credit or cash collateral being posted under certain contractual arrangements.

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

 


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Table of Contents

 

Critical Accounting Estimates

Income Taxes

The amount of income taxes recorded requires interpretations of complex rules and regulations of federal, state, provincial and foreign tax jurisdictions. We recognize current tax expense based on estimated taxable income for the current period and the applicable statutory tax rates. We routinely assess potential uncertain tax positions and, if required, estimate and establish accruals for such amounts. We have recognized deferred tax assets and liabilities for temporary differences, operating losses and other tax carryforwards. We routinely assess our deferred tax assets and reduce such assets by a valuation allowance if we deem it is more likely than not that some portion or all of the deferred tax assets will not be realized. At June 30, 2017, we continued to have a 100% valuation allowance against the U.S. deferred tax assets that largely resulted from prior year cumulative financial losses primarily due to full cost impairments. Further, we continue to record a partial valuation allowance against certain Canadian deferred tax assets.

The accruals for deferred tax assets and liabilities are often based on assumptions that are subject to a significant amount of judgment by management. These assumptions and judgments are reviewed and adjusted as facts and circumstances change. Material changes to our income tax accruals may occur in the future based on the progress of ongoing audits, changes in legislation or resolution of other pending matters.

Non-GAAP Measures

We make reference to “core earnings (loss) attributable to Devon” and “core earnings (loss) per share attributable to Devon” in “Overview of 2017 Results” in this Item 2. that are not required by or presented in accordance with GAAP. These non-GAAP measures are not alternatives to GAAP measures and should not be considered in isolation or as a substitute for analysis of our results reported under GAAP. Core earnings (loss) attributable to Devon, as well as the per share amount, represent net earnings excluding certain noncash and other items that are typically excluded by securities analysts in their published estimates of our financial results. Our non-GAAP measures are typically used as a quarterly performance measure. Amounts excluded for the second quarter and first six months of 2017 relate to changes in derivatives and financial instrument fair values and foreign currency, deferred tax asset valuation allowance, gains and losses on asset sales, noncash asset impairments and gains associated with early retirement of debt. Amounts excluded for the second quarter and first six months of 2016 relate to changes in derivatives and financial instrument fair values and foreign currency, noncash asset impairments (including an impairment of goodwill), deferred tax asset valuation allowance and restructuring and transaction costs. We believe these non-GAAP measures facilitate comparisons of our performance to earnings estimates published by securities analysts. We also believe these non-GAAP measures can facilitate comparisons of our performance between periods and to the performance of our peers.

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Below are reconciliations of our core earnings (loss) and core earnings (loss) per share attributable to Devon to their comparable GAAP measures.

 

 

Three Months Ended June 30,

 

 

Six Months Ended June 30,

 

 

 

Before tax

 

 

After tax

 

 

After Noncontrolling Interests

 

 

Per Diluted Share

 

 

Before tax

 

 

After tax

 

 

After Noncontrolling Interests

 

 

Per Diluted Share

 

 

 

(Millions, except per share amounts)

 

2017

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Earnings attributable to Devon (GAAP)

 

$

458

 

 

$

451

 

 

$

425

 

 

$

0.80

 

 

$

1,056

 

 

$

1,030

 

 

$

990

 

 

$

1.87

 

Adjustments:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Fair value changes in financial

   instruments and foreign currency

 

 

(148

)

 

 

(109

)

 

 

(109

)

 

 

(0.21

)

 

 

(398

)

 

 

(273

)

 

 

(270

)

 

 

(0.51

)

Deferred tax asset valuation allowance

 

 

 

 

 

(128

)

 

 

(128

)

 

 

(0.23

)

 

 

 

 

 

(320

)

 

 

(320

)

 

 

(0.60

)

Gains and losses on asset sales

 

 

(11

)

 

 

(9

)

 

 

(7

)

 

 

(0.01

)

 

 

(7

)

 

 

(5

)

 

 

(5

)

 

 

(0.01

)

Asset impairments

 

 

 

 

 

 

 

 

 

 

 

 

 

 

7

 

 

 

6

 

 

 

3

 

 

 

0.01

 

Early retirement of debt

 

 

(9

)

 

 

(7

)

 

 

(4

)

 

 

(0.01

)

 

 

(9

)

 

 

(7

)

 

 

(4

)

 

 

(0.01

)

Core earnings attributable to Devon

   (Non-GAAP)

 

$

290

 

 

$

198

 

 

$

177

 

 

$

0.34

 

 

$

649

 

 

$

431

 

 

$

394

 

 

$

0.75

 

2016

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Loss attributable to Devon (GAAP)

 

$

(1,745

)

 

$

(1,563

)

 

$

(1,570

)

 

$

(3.04

)

 

$

(5,430

)

 

$

(5,031

)

 

$

(4,626

)

 

$

(9.33

)

Adjustments:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Fair value changes in financial

   instruments and foreign currency

 

 

205

 

 

 

134

 

 

 

130

 

 

 

0.25

 

 

 

217

 

 

 

94

 

 

 

89

 

 

 

0.18

 

Asset impairments

 

 

1,497

 

 

 

990

 

 

 

990

 

 

 

1.91

 

 

 

4,532

 

 

 

3,290

 

 

 

2,874

 

 

 

5.80

 

Deferred tax asset valuation allowance

 

 

 

 

 

467

 

 

 

467

 

 

 

0.91

 

 

 

 

 

 

1,275

 

 

 

1,275

 

 

 

2.57

 

Restructuring and transaction costs

 

 

24

 

 

 

16

 

 

 

16

 

 

 

0.03

 

 

 

271

 

 

 

174

 

 

 

172

 

 

 

0.34

 

Core earnings (loss) attributable to

   Devon (Non-GAAP)

 

$

(19

)

 

$

44

 

 

$

33

 

 

$

0.06

 

 

$

(410

)

 

$

(198

)

 

$

(216

)

 

$

(0.44

)

 

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Table of Contents

Item 3. Quantitative and Qualitative Disclosures About Market Risk

Commodity Price Risk

As of June 30, 2017, we have commodity derivatives that pertain to a portion of our production for the last six months of 2017, as well as 2018. The key terms to our open oil, gas and NGL derivative financial instruments are presented in Note 3 in “Part I. Financial Information – Item 1. Financial Statements” in this report.

The fair values of our commodity derivatives are largely determined by the forward curves of the relevant price indices. At June 30, 2017, a 10% change in the forward curves associated with our commodity derivative instruments would have changed our net asset positions by approximately $150 million.

Interest Rate Risk

As of June 30, 2017, we had total debt of $10.6 billion. Of this amount, $10.4 billion bears fixed interest rates averaging 5.3%, and $231 million is comprised of floating rate debt with interest rates averaging 2.9%.

As of June 30, 2017, we had open interest rate swap positions that are presented in Note 3 in “Part I. Financial Information – Item 1. Financial Statements” in this report. The fair values of our interest rate swaps are largely determined by estimates of the forward curves of the 3-month LIBOR rate. A 10% change in these forward curves would not have materially impacted our balance sheet at June 30, 2017.

Foreign Currency Risk

Our net assets, net earnings and cash flows from our Canadian subsidiaries are based on the U.S. dollar equivalent of such amounts measured in the Canadian dollar functional currency. Assets and liabilities of the Canadian subsidiaries are translated to U.S. dollars using the applicable exchange rate as of the end of a reporting period. Revenues, expenses and cash flow are translated using an average exchange rate during the reporting period. A 10% unfavorable change in the Canadian-to-U.S. dollar exchange rate would not have materially impacted our June 30, 2017 balance sheet.

Our non-Canadian foreign subsidiaries have a U.S. dollar functional currency. However, certain of our subsidiaries hold Canadian-dollar cash and engage in intercompany loans with Canadian subsidiaries that are based in Canadian dollars. The value of the Canadian-dollar cash and intercompany loans increases or decreases from the remeasurement of the cash and loans into the U.S. dollar functional currency.

Item 4. Controls and Procedures

Disclosure Controls and Procedures

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

Based on their evaluation, our principal executive and principal financial officers have concluded that our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934) were effective as of June 30, 2017 to ensure that the information required to be disclosed by Devon in the reports that it files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in the SEC rules and forms.

Changes in Internal Control Over Financial Reporting

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

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Table of Contents

PART II. Other Information

Item 1. Legal Proceedings

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

 

Please see our 2016 Annual Report on Form 10-K for additional information regarding certain environmental matters involving the Company.

Item 1A. Risk Factors

There have been no material changes to the information included in Item 1A. “Risk Factors” in our 2016 Annual Report on Form 10-K.

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

The following table provides information regarding purchases of our common stock that were made by us during the second quarter of 2017.

 

Period

 

Total Number of

Shares Purchased (1)

 

 

Average Price Paid

per Share

 

April 1 - April 30

 

 

24,254

 

 

$

39.74

 

May 1 - May 31

 

 

32,453

 

 

$

38.09

 

June 1 - June 30

 

 

1,633

 

 

$

32.09

 

Total

 

 

58,340

 

 

$

38.61

 

 

(1)

Share repurchases represent shares received by us from employees for the payment of personal income tax withholding on vesting transactions.

Under the Devon Plan, eligible employees may 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 12,900 shares of our common stock in the second quarter of 2017, at then-prevailing stock prices, that they held through their ownership in the Stock Fund. We acquired the shares of our common stock sold under the Devon Plan through open-market purchases.

Similarly, eligible Canadian employees may purchase shares of our common stock through an investment in the Canadian Plan, which is administered by an independent trustee, Sun Life Assurance Company of Canada. Shares sold under the Canadian Plan were acquired through open-market purchases. These shares and any interest in the Canadian Plan were offered and sold in reliance on the exemptions for offers and sales of securities made outside of the U.S., including under Regulation S for offers and sales of securities to employees pursuant to an employee benefit plan established and administered in accordance with the law of a country other than the U.S. In the second quarter of 2017, there were no shares purchased by Canadian employees.

Item 3. Defaults Upon Senior Securities

Not applicable.

Item 4. Mine Safety Disclosures

Not applicable.

Item 5. Other Information

Not applicable.

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Table of Contents

Item 6. Exhibits

 

Exhibit

Number

 

Description

 

 

10.1

2017 Form of Notice of Grant of Restricted Stock Award and Award Agreement under the 2017 Long-Term Incentive Plan between Devon and all non-management directors for restricted stock awards.*

 

 

10.2

Devon Energy Corporation 2017 Long-Term Incentive Plan (incorporated by reference to Exhibit 99.1 to Devon’s Registration Statement on Form S-8, filed on June 7, 2017; File No. 333-218561).*

 

 

10.3

Employment Agreement, dated April 19, 2017, by and between Devon and Mr. Jeffrey L. Ritenour (incorporated by reference to Exhibit 10.1 to Devon’s Form 8-K, filed on April 20, 2017; File No. 001-32318).*

 

 

  31.1

 

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

 

 

  31.2

 

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

 

 

  32.1

 

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

 

 

  32.2

 

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

 

 

101.INS

 

XBRL Instance Document.

 

 

101.SCH

 

XBRL Taxonomy Extension Schema Document.

 

 

101.CAL

 

XBRL Taxonomy Extension Calculation Linkbase Document.

 

 

101.DEF

 

XBRL Taxonomy Extension Definition Linkbase Document.

 

 

101.LAB

 

XBRL Taxonomy Extension Labels Linkbase Document.

 

 

101.PRE

 

XBRL Taxonomy Extension Presentation Linkbase Document.

_________________

* Indicates management contract or compensatory plan or arrangement.

 

 

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Table of Contents

SIGNATURES

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

 

 

 

 

 

DEVON ENERGY CORPORATION

 

 

 

Date: August 2, 2017

 

 

 

/s/ Jeremy D. Humphers

 

 

 

 

Jeremy D. Humphers

 

 

 

 

Senior Vice President and Chief Accounting Officer

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Table of Contents

INDEX TO EXHIBITS

 

 

Exhibit

Number

 

Description

 

 

10.1

2017 Form of Notice of Grant of Restricted Stock Award and Award Agreement under the 2017 Long-Term Incentive Plan between Devon and all non-management directors for restricted stock awards.*

 

 

10.2

Devon Energy Corporation 2017 Long-Term Incentive Plan (incorporated by reference to Exhibit 99.1 to Devon’s Registration Statement on Form S-8, filed on June 7, 2017; File No. 333-218561).*

 

 

10.3

Employment Agreement, dated April 19, 2017, by and between Devon and Mr. Jeffrey L. Ritenour (incorporated by reference to Exhibit 10.1 to Devon’s Form 8-K, filed on April 20, 2017; File No. 001-32318).*

 

 

  31.1

 

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

 

 

  31.2

 

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

 

 

  32.1

 

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

 

 

  32.2

 

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

 

 

101.INS

 

XBRL Instance Document.

 

 

101.SCH

 

XBRL Taxonomy Extension Schema Document.

 

 

101.CAL

 

XBRL Taxonomy Extension Calculation Linkbase Document.

 

 

101.DEF

 

XBRL Taxonomy Extension Definition Linkbase Document.

 

 

101.LAB

 

XBRL Taxonomy Extension Labels Linkbase Document.

 

 

101.PRE

 

XBRL Taxonomy Extension Presentation Linkbase Document.

_________________

* Indicates management contract or compensatory plan or arrangement.

 

 

46