Form 8-K

8-K — DEVON ENERGY CORP/DE

Accession: 0001193125-26-332824

Filed: 2026-08-04

Period: 2026-08-04

CIK: 0001090012

SIC: 1311 (CRUDE PETROLEUM & NATURAL GAS)

Item: Results of Operations and Financial Condition

Item: Financial Statements and Exhibits

Documents

8-K — d359332d8k.htm (Primary)

EX-99.1 (d359332dex991.htm)

EX-99.2 (d359332dex992.htm)

GRAPHIC (g359332dsp4.jpg)

XML — IDEA: XBRL DOCUMENT (R1.htm)

8-K

8-K (Primary)

Filename: d359332d8k.htm · Sequence: 1

8-K

DEVON ENERGY CORP/DE false 0001090012 0001090012 2026-08-04 2026-08-04

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 8-K

CURRENT REPORT

Pursuant to Section 13 or 15(d)

of The Securities Exchange Act of 1934

Date of Report (Date of earliest event reported): August 4, 2026

Devon Energy Corporation

(Exact name of registrant as specified in its charter)

Delaware

001-32318

73-1567067

(State or other jurisdiction

of incorporation)

(Commission

File Number)

(IRS Employer

Identification No.)

THREE MEMORIAL CITY PLAZA

840 GESSNER ROAD, SUITE 1400

HOUSTON, Texas 77024

(Address of principal executive offices)

Registrant’s telephone number, including area code: (281) 589-4600

Not Applicable

(Former name or former address, if changed since last report)

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:

☐

Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

☐

Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

☐

Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

☐

Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

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

Title of each class

Trading

Symbol(s)

Name of each exchange

on which registered

Common Stock, par value $0.10 per share

DVN

The New York Stock Exchange

Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§ 230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§ 240.12b-2 of this chapter).

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. ☐

Item 2.02

Results of Operations and Financial Condition.

On August 4, 2026, Devon Energy Corporation (the “Company”) announced its financial and operational results for the quarterly period ended June 30, 2026. In connection with this announcement, the Company provided an earnings release and certain supplemental financial information (including guidance and hedging information). Copies of these documents are furnished as Exhibits 99.1 and 99.2, respectively, to this report and, along with certain other materials, will be available on the Company’s website at www.devonenergy.com.

The information contained in this report and the exhibits hereto shall not be deemed to be “filed” for purposes of Section 18 of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), and shall not be incorporated by reference into any filings made by the Company under the Securities Act of 1933, as amended, or the Exchange Act, except as may be expressly set forth by specific reference in such filing.

Item 9.01

Financial Statements and Exhibits.

(d) Exhibits

Exhibit

No.

Description of Exhibits

99.1

Earnings release, dated August 4, 2026.

99.2

Supplemental financial information (including guidance and hedging information).

104

Cover Page Interactive Data File (embedded within the Inline XBRL document).

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 hereunto duly authorized.

DEVON ENERGY CORPORATION

By:

/s/ Gregory F. Conaway

Gregory F. Conaway

Vice President and Chief Accounting Officer

Date: August 4, 2026

EX-99.1

Filename: d359332dex991.htm · Sequence: 2

EX-99.1

Exhibit 99.1

Devon Energy Corporation

Three Memorial City Plaza

840 Gessner Road,

Suite 1400

Houston, TX 77024

Devon Energy Reports Second-Quarter 2026 Results

HOUSTON, TX – August 4, 2026 – Devon Energy Corporation (NYSE: DVN) today reports second-quarter 2026 results.

Supplemental financial tables and forward-looking guidance are available on the company’s website at www.devonenergy.com.

KEY FINANCIAL,

OPERATIONAL & STRATEGIC HIGHLIGHTS

•

Transformative Merger Complete: Closed the merger with Coterra Energy on May 7, only 94 days after

announcement, creating a premier large-cap operator

•

Production Outperformance: Averaged 503,000 barrels of oil production per day in the second quarter,

reaching the top-end of guidance

•

Disciplined Capital Management: Invested $1,269 million of capital in the second quarter,

2 percent below midpoint guidance

•

Robust Cash Generation: Operations generated $3.7 billion of operating cash flow (GAAP), adjusted

operating cash flow of $2.9 billion and $1.7 billion of adjusted free cash flow during the second quarter, excluding the impact of after-tax restructuring costs

•

Accelerated Shareholder Returns: Returned $1,063 million during the quarter through a combination of

an increased quarterly dividend of $0.32 per share, renewed share repurchases and retirement of maturing debt

•

Core Delaware Expansion: Acquired 16,300 net acres and approximately 400

top-tier locations, with favorable terms (87.5% NRI), in the heart of the Delaware Basin at the New Mexico federal lease sale

•

Comprehensive Portfolio Review Underway: Conducting a rigorous, asset-by-asset evaluation focused on multiple factors including capital efficiency, free cash flow contribution and strategic fit, with the sole objective of maximizing shareholder value

•

Synergy Capture on Track: On track to deliver at least $1.0 billion of annual pre-tax synergies on a run-rate basis by year-end 2027, with approximately $600 million expected to be captured during 2027

CEO COMMENTARY

“Devon’s first quarter as a combined company demonstrated the full power of this platform, with results that outperformed across every major value

driver,” said Clay Gaspar, president and CEO. “We delivered 503,000 barrels of oil per day at the top end of guidance, delivered capital expenditures 2 percent below expectations and generated $1.7 billion of adjusted free cash

flow, all while moving at full speed on integration. These results reflect the talent and commitment of our newly combined teams, which have not missed a beat in the field.”

“Since merger close, we have moved with speed and intention,” Gaspar added. “We returned more than $1 billion through our dividend,

share repurchases and debt repayment, strengthened an already premier Delaware Basin position with a once-in-a-generation federal

lease sale, and advanced synergy capture with more than 350 initiatives underway. Our confidence in delivering at least $1 billion in synergies continues to increase.”

“Looking ahead, our priorities are clear: continuing integration and operational excellence, delivering on our synergy commitments, moving decisively

through our portfolio review and returning meaningful capital to shareholders,” Gaspar concluded. “With the scale and quality of this portfolio, a fortress balance sheet, and a peer-leading free cash flow outlook, Devon is an energy

powerhouse, built to deliver differentiated returns to our owners through all phases of the commodity cycle.”

FINANCIAL RESULTS

Devon reported net earnings of $1.9 billion, or $2.03 per diluted share, in the second quarter of 2026. Adjusting for items analysts typically exclude

from estimates, the company’s core earnings were $1.5 billion, or $1.57 per diluted share.

Devon’s operating cash flow totaled $3.7 billion in the second quarter, reflecting the results of

combined operations following the May 7 closing of the Coterra merger. The company funded its capital requirements and had $1.7 billion in adjusted free cash flow for the quarter, excluding the impact of $174 million of after-tax restructuring costs during the quarter.

During the quarter, Devon retired $250 million of senior notes,

retired $250 million of its term loan, and funded its $2.6 billion New Mexico federal lease acquisition with cash on hand, in addition to funding its dividend and seven weeks of its base share repurchase program.

At the end of the second quarter, Devon had a cash balance of $1.0 billion and an undrawn credit facility of $3.0 billion. Outstanding debt totaled

$11.4 billion. In July, Devon retired the remaining $750 million of its term loan. The company has no outstanding maturities until the second quarter of 2027.

RETURN OF CAPITAL

Following the close of the merger with

Coterra Energy, Devon’s board of directors approved a 33 percent increase to the quarterly fixed dividend rate to $0.32 per share, consistent with the company’s strategic priority of delivering value to shareholders through a

sustainable, annually growing fixed dividend. The second-quarter dividend totaled $366 million and was paid on Jun. 30, 2026. For the third quarter, Devon declared a fixed quarterly cash dividend of $0.32 per share, payable on Sep. 30, 2026, to

shareholders of record at the close of business on Sep. 15, 2026.

The company also returned capital to shareholders through its new $8.0 billion

share repurchase program, approved by the board in conjunction with the merger close. Upon close, Devon quickly resumed repurchase activity. During the last seven weeks of the second quarter, the company repurchased 4.3 million shares for

$197 million, leaving $7.8 billion of remaining capacity on the authorization, which extends through mid-2029.

OPERATING RESULTS

Devon’s operational activity in

the second quarter averaged 34 operated drilling rigs and 10 completion crews. This level of activity resulted in 120 net operated wells being placed online, with an average lateral length of 10,800 feet. Capital expenditures totaled

$1,269 million, or 2 percent below the guidance midpoint. This positive variance was primarily attributable to timing and effective cost management.

During the quarter, Devon acquired 16,300 net acres in the heart of the Delaware Basin at the New Mexico federal lease sale for $2.6 billion, adding

approximately 400 top-tier, 87.5% Net Revenue Interest locations, funded with cash on hand. Devon plans to begin development of the acquired acreage during 2027.

Production averaged 1,359,000 Boe per day in the second quarter, reaching the top-end of guidance. Oil totaled 503,000

barrels per day in the quarter, which was at the top-end of the company’s guidance. This positive result was driven by better-than-expected well performance, primarily in the Delaware Basin.

For the second quarter, Devon’s oil, gas and NGL sales totaled $5.1 billion. The company’s realized price during the period, including

commodity hedges, was $88.09 per barrel of oil, $22.70, per barrel of NGL, and $1.05 per Mcf of natural gas. Oil realizations were exceptionally strong, supported by robust crude benchmark pricing during the quarter, while natural gas realizations

were depressed by regional Waha pricing driven by infrastructure constraints in the Delaware Basin.

Production costs, including production and property

taxes, averaged $11.27 per Boe in the second quarter. The largest component of production costs is lease operating expense, which totaled $5.06 per Boe in the quarter, below midpoint of annual guidance expectations.

Underpinning these results is the rapid progress of the company’s merger integration efforts. With more than 350 individual initiatives identified,

Devon is on track to deliver at least $1.0 billion of annual pre-tax run-rate synergies by year-end 2027, with approximately

$600 million expected to be captured during 2027. These actions, driven by shared best practices and technology, are strengthening margins and increasing capital efficiency across the combined portfolio.

2026 OUTLOOK

After a strong second-quarter, the company is demonstrating the operational and financial performance which underpin its full-year 2026 guidance, which remains

unchanged from June.

In the third quarter of 2026, total production is expected to average between 1,660,000 and 1,690,000 Boe per day and oil production

is expected to average between 550,000 and 560,000 barrels per day. Capital spending in the third quarter is expected to be between $1,400 million and $1,500 million.

Additional details of Devon’s forward-looking guidance are available on the company’s website at www.devonenergy.com.

CONFERENCE CALL WEBCAST AND SUPPLEMENTAL EARNINGS MATERIALS

Also provided with today’s release is the company’s earnings presentation, available on the company’s website at www.devonenergy.com.

The company’s second-quarter conference call will be held at 10:00 a.m. Central (11:00 a.m. Eastern) on August 5, 2026, and will serve primarily as a forum for analyst and investor questions and answers.

ABOUT DEVON ENERGY

Devon Energy is a leading oil and gas

producer in the U.S. with a diversified multi-basin portfolio headlined by a world-class acreage position in the Delaware Basin. Devon’s disciplined cash-return business model is designed to achieve strong returns, generate free cash flow and

return capital to shareholders, while focusing on safe and sustainable operations. For more information, please visit www.devonenergy.com.

Investor Contact

Media Contact

investor.relations@dvn.com

Michelle Hindmarch

405-228-4450

405-552-7460

NON-GAAP DISCLOSURES

This press release includes non-GAAP (generally accepted accounting principles) financial measures. Such non-GAAP measures are not alternatives to GAAP measures, and you should not consider these non-GAAP measures in isolation or as a substitute for analysis of results as

reported under GAAP. Reconciliations of these non-GAAP measures and other disclosures are provided within the supplemental financial tables that are available on the company’s website.

FORWARD-LOOKING STATEMENTS

This press release

includes “forward-looking statements” within the meaning of the federal securities laws. Such statements include those concerning strategic plans, our expectations and objectives for future operations, as well as other future events or

conditions, and are often identified by use of the words and phrases “expects,” “believes,” “will,” “would,” “could,” “continue,” “may,” “aims,”

“likely to be,” “intends,” “forecasts,” “projections,” “estimates,” “plans,” “expectations,” “targets,” “opportunities,”

“potential,” “anticipates,” “outlook” and other similar terminology. All statements, other than statements of historical facts, included in this press release that address activities, events or developments that

Devon expects, believes or anticipates will or may occur in the future are forward-looking statements. Such statements are subject to a number of assumptions, risks and uncertainties, many of which are beyond our control. Consequently, actual future

results could differ materially and adversely from our expectations due to a number of factors, including, but not limited to: the volatility of oil, gas and NGL prices, including from the impact of ongoing or escalating armed conflicts, wars and

geopolitical instability and from changes in trade relations and policies, such as the imposition of new or increased tariffs or other trade protection measures by the U.S., China or other countries; uncertainties inherent in estimating oil, gas and

NGL reserves; the extent to which we are successful in acquiring and discovering additional reserves; the uncertainties, costs and risks involved in our operations; risks related to our hedging activities; our limited control over third parties who

operate some of our oil and gas properties and investments; midstream capacity constraints and potential interruptions in production, including from limits to the build out of midstream infrastructure; competition for assets, materials, people and

capital, which can be exacerbated by supply chain disruptions, including as a result of tariffs or other changes in trade policy; regulatory restrictions, compliance costs and other risks relating to governmental regulation, including with respect

to federal lands, environmental matters, water disposal and tax matters; climate change and risks related to regulatory, social and market efforts to address climate change; risks relating to our sustainability initiatives; claims, litigation,

audits and other proceedings impacting our business, including with respect to historic and legacy operations; governmental interventions in energy markets; counterparty credit risks; risks relating to our indebtedness; cybersecurity risks; risks

associated with artificial intelligence and other emerging technologies; the extent to which insurance covers any losses we may experience; risks related to shareholder activism; our ability to successfully complete mergers, acquisitions and

divestitures; our ability to pay dividends and make share repurchases; risks related to the merger with Coterra, including the risk that we may not realize the anticipated synergies or other benefits of the merger or successfully integrate the two

legacy businesses; and any of the other risks and uncertainties discussed in Devon’s 2025 Annual Report on Form 10-K (the “2025 Form 10-K”) or other

filings with the SEC.

The forward-looking statements included in this press release speak only as of the date of this press

release, represent management’s current reasonable expectations as of the date of this press release and are subject to the risks and uncertainties identified above as well as those described elsewhere in the 2025 Form 10-K and in other documents we file from time to time with the SEC. We cannot guarantee the accuracy of our forward-looking statements, and readers are urged to carefully review and consider the various disclosures

made in the 2025 Form 10-K and in other documents we file from time to time with the SEC. All subsequent written and oral forward-looking statements attributable to Devon, or persons acting on its behalf, are

expressly qualified in their entirety by the cautionary statements above. We do not undertake, and expressly disclaim, any duty to update or revise our forward-looking statements based on new information, future events or otherwise.

EX-99.2

Filename: d359332dex992.htm · Sequence: 3

EX-99.2

Exhibit 99.2

Devon Energy Second-Quarter 2026

Supplemental Tables

TABLE OF CONTENTS:

PAGE:

Consolidated Statements of Earnings

Supplemental Information for Consolidated Statements of Earnings

Consolidated Balance Sheets

Consolidated Statements of Cash Flows

Production

Capital Expenditures and Supplemental Information for Capital Expenditures

Realized Pricing

Asset Margins

Core Earnings

EBITDAX

Net Debt, Net

Debt-to-EBITDAX, Free Cash Flow and Reinvestment Rate

CONSOLIDATED STATEMENTS OF EARNINGS

(in millions, except per share amounts)

2026

2025

Quarter 2

Quarter 1

Quarter 4

Quarter 3

Quarter 2

Oil, gas and NGL sales

5,106

2,977

2,578

2,809

2,710

Oil, gas and NGL derivatives (1)

414

(701

)

184

236

Marketing and midstream revenues

1,897

1,531

1,359

1,442

1,338

Total revenues

7,417

3,807

4,121

4,331

4,284

Production expenses (2)

1,393

894

861

895

899

Exploration expenses

Marketing and midstream expenses

1,874

1,547

1,389

1,453

1,357

Depreciation, depletion and amortization

1,416

904

890

879

914

Asset dispositions

(25

)

(37

)

(307

)

General and administrative expenses

175

125

135

114

113

Financing costs, net (3)

125

109

107

109

116

Restructuring and transaction costs

246

—

Other, net

(187

)

(12

)

(11

)

Total expenses

5,033

3,641

3,374

3,419

3,123

Earnings before income taxes

2,384

166

747

912

1,161

Income tax expense (4)

473

185

219

244

Net earnings

1,911

120

562

693

917

Net earnings attributable to noncontrolling interests

—

Net earnings attributable to Devon

1,911

120

562

687

899

Net earnings per share:

Basic net earnings per share

2.04

0.19

0.91

1.09

1.42

Diluted net earnings per share

2.03

0.19

0.90

1.09

1.41

Weighted average common shares outstanding:

Basic

937

616

621

628

635

Diluted

940

618

622

629

636

SUPPLEMENTAL INFORMATION FOR CONSOLIDATED STATEMENTS OF EARNINGS

(1) OIL, GAS AND NGL DERIVATIVES

(in millions)

2026

2025

Quarter 2

Quarter 1

Quarter 4

Quarter 3

Quarter 2

Derivative cash settlements

(116

)

(57

)

125

Derivative valuation changes

530

(644

)

169

Oil, gas and NGL derivatives

414

(701

)

184

236

(2) PRODUCTION EXPENSES

(in millions)

2026

2025

Quarter 2

Quarter 1

Quarter 4

Quarter 3

Quarter 2

Lease operating expense

626

486

479

481

483

Gathering, processing & transportation

391

191

195

213

219

Production taxes

357

205

172

184

180

Property taxes

Production expenses

1,393

894

861

895

899

(3) FINANCING COSTS, NET

(in millions)

2026

2025

Quarter 2

Quarter 1

Quarter 4

Quarter 3

Quarter 2

Interest based on debt outstanding

144

118

119

125

126

Interest income

(22

)

(14

)

(14

)

(18

)

(14

)

Other

Financing costs, net

125

109

107

109

116

(4) INCOME TAX EXPENSE

(in millions)

2026

2025

Quarter 2

Quarter 1

Quarter 4

Quarter 3

Quarter 2

Current expense (benefit)

378

(188

)

(44

)

226

Deferred expense

234

162

263

Income tax expense (1)

473

185

219

244

(1)

Devon recognized a one-time current tax benefit of approximately

$218 million in Q1 2026 related to new tax guidance under the One Big Beautiful Bill Act. With that benefit pulled into Q1 and higher oil pricing, Q2’s 2026 current tax rate reflects a normalized

go-forward run-rate.

CONSOLIDATED BALANCE SHEETS

(in millions)

2026

2025

Quarter 2

Quarter 1

Quarter 4

Quarter 3

Quarter 2

Current assets:

Cash, cash equivalents and restricted cash

1,009

1,815

1,434

1,278

1,759

Accounts receivable

3,162

2,250

1,792

1,835

1,853

Inventory

356

319

336

361

327

Other current assets

522

378

444

393

384

Total current assets

5,049

4,762

4,006

3,867

4,323

Oil and gas property and equipment, based on successful efforts accounting, net

60,899

23,912

23,731

23,591

23,428

Other property and equipment, net

2,199

1,686

1,688

1,698

1,687

Total property and equipment, net

63,098

25,598

25,419

25,289

25,115

Goodwill

753

Right-of-use

assets

509

312

299

247

185

Investments

992

715

727

679

640

Other long-term assets

492

403

395

386

374

Total assets

70,893

32,543

31,599

31,221

31,390

Current liabilities:

Accounts payable

1,626

975

790

934

885

Revenues and royalties payable

2,451

1,678

1,491

1,464

1,440

Short-term debt

1,497

999

998

485

Income taxes payable

414

—

152

126

190

Other current liabilities

1,052

1,082

655

520

537

Total current liabilities

7,040

4,734

4,086

4,042

3,537

Long-term debt

9,891

7,387

7,391

7,393

8,393

Lease liabilities

356

206

197

158

113

Asset retirement obligations

1,169

986

863

850

839

Other long-term liabilities

1,043

940

907

962

1,008

Deferred income taxes

9,647

2,862

2,627

2,466

2,208

Stockholders’ equity:

Common stock

115

Additional paid-in capital

30,045

5,316

5,388

5,618

5,864

Retained earnings

11,712

10,171

10,200

9,788

9,252

Accumulated other comprehensive loss

(120

)

(121

)

(122

)

(119

)

(120

)

Treasury stock

)

—

Total stockholders’ equity attributable to Devon

41,747

15,428

15,528

15,350

15,060

Noncontrolling interests

—

232

Total equity

41,747

15,428

15,528

15,350

15,292

Total liabilities and equity

70,893

32,543

31,599

31,221

31,390

CONSOLIDATED STATEMENTS OF CASH FLOWS

(in millions)

2026

2025

Quarter 2

Quarter 1

Quarter 4

Quarter 3

Quarter 2

Cash flows from operating activities:

Net earnings

1,911

120

562

693

917

Adjustments to reconcile net earnings to net cash from operating activities:

Depreciation, depletion and amortization

1,416

904

890

879

914

Leasehold impairments

)

Accretion of liabilities

Total (gains) losses on commodity derivatives

(414

)

701

(184

)

(80

)

(236

)

Cash settlements on commodity derivatives

(116

)

(57

)

125

(Gains) losses on asset dispositions

(25

)

(37

)

(307

)

Deferred income tax expense

234

162

263

Share-based compensation

Other

(204

)

(45

)

Changes in assets and liabilities, net

924

(299

)

(38

)

(62

)

134

Net cash from operating activities

3,674

1,655

1,534

1,690

1,545

Cash flows from investing activities:

Cash acquired in Merger

581

—

Capital expenditures

(1,318

)

(839

)

(832

)

(870

)

(956

)

Acquisitions of property and equipment

(2,729

)

(190

)

(101

)

(197

)

(16

)

Divestitures of property and equipment and investments

372

Distributions from investments

Contributions to investments and other

(10

)

(50

)

Net cash from investing activities

(3,375

)

(1,020

)

(970

)

(1,024

)

(597

)

Cash flows from financing activities:

Repayments of long-term debt

(500

)

—

(485

)

—

Repurchases of common stock

(197

)

(69

)

(250

)

(250

)

(249

)

Dividends paid on common stock

(366

)

(155

)

(149

)

(151

)

(156

)

Distributions to noncontrolling interests

—

(14

)

Acquisition of noncontrolling interests

—

(260

)

—

Repayment of finance leases

)

—

Shares exchanged for tax withholdings and other

(44

)

(27

)

—

)

Net cash from financing activities

(1,109

)

(254

)

(407

)

(1,147

)

(424

)

Effect of exchange rate changes on cash

—

)

—

Net change in cash, cash equivalents and restricted cash

(806

)

381

156

(481

)

525

Cash, cash equivalents and restricted cash at beginning of period

1,815

1,434

1,278

1,759

1,234

Cash, cash equivalents and restricted cash at end of period

1,009

1,815

1,434

1,278

1,759

Reconciliation of cash, cash equivalents and restricted cash:

Cash and cash equivalents

950

1,763

1,384

1,229

1,713

Restricted cash

Total cash, cash equivalents and restricted cash

1,009

1,815

1,434

1,278

1,759

PRODUCTION

2026

2025

Quarter 2

Quarter 1

Quarter 4

Quarter 3

Quarter 2

Oil (MBbls/d)

Permian

329

225

234

223

228

Rockies

105

103

102

111

104

Eagle Ford

Anadarko

Marcellus

—

Other

Total

503

387

390

387

Natural gas liquids (MBbls/d)

Permian

206

137

146

134

133

Rockies

Eagle Ford

Anadarko

Marcellus

—

Other

—

Total

314

218

231

228

222

Gas (MMcf/d)

Permian

1,274

831

848

834

823

Rockies

237

230

234

245

228

Eagle Ford

Anadarko

396

235

246

261

274

Marcellus

1,258

—

Other

—

Total

3,252

1,373

1,385

1,410

1,388

Total oil equivalent (MBoe/d)

Permian

748

501

521

496

498

Rockies

192

187

192

205

189

Eagle Ford

Anadarko

128

Marcellus

210

—

Other

Total

1,359

833

851

853

841

CAPITAL EXPENDITURES

(in millions)

2026

2025

Quarter 2

Quarter 1

Quarter 4

Quarter 3

Quarter 2

Permian

731

451

454

465

482

Rockies

196

218

231

191

228

Eagle Ford

120

137

141

122

Anadarko

129

Marcellus

—

Other

Total upstream capital

1,226

828

856

823

879

Midstream and Corporate

Capital expenditures

1,269

848

883

859

932

Acquisitions

2,729

151

141

197

Total capital

3,998

999

1,024

1,056

948

SUPPLEMENTAL INFORMATION FOR CAPITAL EXPENDITURES

GROSS OPERATED SPUDS

2026

2025

Quarter 2

Quarter 1

Quarter 4

Quarter 3

Quarter 2

Permian

103

Rockies

Eagle Ford

Anadarko

Marcellus

—

Total

150

103

100

115

113

GROSS OPERATED WELLS TIED-IN

2026

2025

Quarter 2

Quarter 1

Quarter 4

Quarter 3

Quarter 2

Permian

Rockies

Eagle Ford

Anadarko

—

Marcellus

—

Total

157

110

102

110

NET OPERATED WELLS TIED-IN

2026

2025

Quarter 2

Quarter 1

Quarter 4

Quarter 3

Quarter 2

Permian

Rockies

Eagle Ford

Anadarko

—

Marcellus

—

Total

120

AVERAGE LATERAL LENGTH

(based on wells tied-in)

2026

2025

Quarter 2

Quarter 1

Quarter 4

Quarter 3

Quarter 2

Permian

10,600’

11,000’

11,800’

11,100’

10,500’

Rockies

11,500’

12,500’

11,600’

13,000’

12,300’

Eagle Ford

8,900’

7,000’

5,900’

7,200’

8,200’

Anadarko

10,000’

—

10,100’

10,000’

Marcellus

14,000’

—

Total

10,800’

10,500’

10,200’

10,300’

REALIZED PRICING

BENCHMARK PRICES

(average prices)

2026

2025

Quarter 2

Quarter 1

Quarter 4

Quarter 3

Quarter 2

Oil ($/Bbl) - West Texas Intermediate (Cushing)

92.47

72.10

59.09

64.92

63.95

Natural Gas ($/Mcf) - Henry Hub

2.90

5.05

3.55

3.07

3.44

NGL ($/Bbl) - Mont Belvieu Blended

29.23

24.86

23.67

24.25

25.58

REALIZED PRICES

2026

2025

Quarter 2

Quarter 1

Quarter 4

Quarter 3

Quarter 2

Oil (Per Bbl)

Permian

96.08

70.89

57.94

63.89

62.60

Rockies

92.01

67.14

54.99

61.14

59.05

Eagle Ford

95.89

68.98

58.18

64.87

63.14

Anadarko

94.92

70.24

57.46

63.68

62.09

Marcellus

—

Realized price without hedges

95.10

69.66

57.19

63.21

61.70

Cash settlements

(7.01

)

(1.72

)

2.47

0.78

1.27

Realized price, including cash settlements

88.09

67.94

59.66

63.99

62.97

Natural gas liquids (Per Bbl)

Permian

23.29

19.60

18.42

18.25

19.10

Rockies

15.11

7.83

9.02

10.26

9.27

Eagle Ford

27.44

24.54

22.28

22.85

23.03

Anadarko

26.17

23.23

21.50

20.94

22.41

Marcellus

—

Realized price without hedges

22.70

17.80

16.86

17.01

17.71

Cash settlements

—

0.23

0.17

0.11

Realized price, including cash settlements

22.70

17.80

17.09

17.18

17.82

Gas (Per Mcf)

Permian

(2.03

)

0.73

0.96

1.50

1.34

Rockies

(0.64

)

1.80

0.33

(0.42

)

(0.50

)

Eagle Ford

2.36

4.01

3.14

2.78

3.01

Anadarko

2.40

4.03

3.13

2.57

2.86

Marcellus

2.17

—

Realized price without hedges

0.35

1.66

1.33

1.43

1.41

Cash settlements

0.70

0.02

0.25

0.15

Realized price, including cash settlements

1.05

1.68

1.58

1.56

Total oil equivalent (Per Boe)

Permian

45.28

38.44

32.72

36.18

35.92

Rockies

53.31

41.18

32.04

35.33

34.29

Eagle Ford

67.86

53.11

45.82

48.85

48.32

Anadarko

29.02

31.29

25.62

23.97

25.28

Marcellus

13.02

—

Realized price without hedges

41.30

39.70

32.92

35.82

35.43

Cash settlements

(0.94

)

(0.76

)

1.60

0.64

0.87

Realized price, including cash settlements

40.36

38.94

34.52

36.46

36.30

ASSET MARGINS

BENCHMARK PRICES

(average prices)

2026

2025

Quarter 2

Quarter 1

Quarter 4

Quarter 3

Quarter 2

Oil ($/Bbl) - West Texas Intermediate (Cushing)

92.47

72.10

59.09

64.92

63.95

Natural Gas ($/Mcf) - Henry Hub

2.90

5.05

3.55

3.07

3.44

NGL ($/Bbl) - Mont Belvieu Blended

29.23

24.86

23.67

24.25

25.58

PER-UNIT CASH MARGIN

BY ASSET (per Boe)

2026

2025

Quarter 2

Quarter 1

Quarter 4

Quarter 3

Quarter 2

Permian

Realized price

45.28

38.44

32.72

36.18

35.92

Lease operating expenses

(5.39

)

(5.19

)

(5.11

)

(5.38

)

(5.54

)

Gathering, processing & transportation

(2.81

)

(2.57

)

(2.57

)

(2.94

)

(3.17

)

Production & property taxes

(3.69

)

(2.91

)

(2.44

)

(2.52

)

(2.63

)

Field-level cash margin

33.39

27.77

22.60

25.34

24.58

Rockies

Realized price

53.31

41.18

32.04

35.33

34.29

Lease operating expenses

(8.87

)

(10.02

)

(9.05

)

(8.27

)

(9.13

)

Gathering, processing & transportation

(1.03

)

(1.04

)

(1.03

)

(0.99

)

(0.86

)

Production & property taxes

(4.43

)

(3.32

)

(2.64

)

(3.04

)

(2.85

)

Field-level cash margin

38.98

26.80

19.32

23.03

21.45

Eagle Ford

Realized price

67.86

53.11

45.82

48.85

48.32

Lease operating expenses

(6.72

)

(7.98

)

(7.90

)

(7.83

)

(7.52

)

Gathering, processing & transportation

(2.34

)

(2.14

)

(1.98

)

(2.27

)

(1.94

)

Production & property taxes

(3.41

)

(2.81

)

(2.43

)

(2.89

)

(3.02

)

Field-level cash margin

55.39

40.18

33.51

35.86

35.84

Anadarko

Realized price

29.02

31.29

25.62

23.97

25.28

Lease operating expenses

(3.18

)

(3.76

)

(3.19

)

(3.25

)

(2.98

)

Gathering, processing & transportation

(5.45

)

(6.64

)

(6.19

)

(5.98

)

(6.13

)

Production & property taxes

(1.55

)

(1.71

)

(1.22

)

(1.30

)

(1.32

)

Field-level cash margin

18.84

19.18

15.02

13.44

14.85

Marcellus

Realized price

13.02

—

Lease operating expenses

(0.59

)

—

Gathering, processing & transportation

(5.36

)

—

Production & property taxes

(0.18

)

—

Field-level cash margin

6.89

—

Devon - Total

Realized price

41.30

39.70

32.92

35.82

35.43

Lease operating expenses

(5.06

)

(6.48

)

(6.11

)

(6.14

)

(6.31

)

Gathering, processing & transportation

(3.16

)

(2.54

)

(2.49

)

(2.71

)

(2.86

)

Production & property taxes

(3.05

)

(2.90

)

(2.39

)

(2.56

)

(2.58

)

Field-level cash margin

30.03

27.78

21.93

24.41

23.68

NON-GAAP MEASURES

(all monetary values in millions, except

per share amounts)

Devon’s earnings materials include non-GAAP financial measures. These non-GAAP measures are not alternatives to GAAP measures, and you should not consider these non-GAAP measures in isolation or as a substitute for analysis of our results as

reported under GAAP. Below is additional disclosure regarding each of the non-GAAP measures used in the earnings materials, including reconciliations to their most directly comparable GAAP measure.

The earnings materials may include forward-looking non-GAAP measures. The company is unable to provide reconciliations

of these forward-looking non-GAAP measures, because components of the calculations are inherently unpredictable, such as changes to current assets and liabilities, the timing of changes in capital accruals,

unknown future events and estimating certain future GAAP measures. The inability to reliably quantify certain components of the calculation would significantly affect the usefulness and accuracy of a reconciliation.

CORE EARNINGS

Devon’s reported net earnings

include items of income and expense that are typically excluded by securities analysts in their published estimates of the company’s financial results. Accordingly, the company also uses the measures of core earnings and core earnings per

share attributable to Devon. Devon believes these non-GAAP measures facilitate comparisons of its performance to earnings estimates published by securities analysts. Devon also believes these non-GAAP measures can facilitate comparisons of its performance between periods and to the performance of its peers. The following table summarizes the effects of these items on second-quarter 2026 and first-quarter

2026 earnings.

Quarter Ended June 30, 2026

Before-tax

After-tax

After NCI

Per Diluted

Total

Earnings (GAAP)

2,384

1,911

2.03

Adjustments:

Asset dispositions

(25

)

(20

)

(20

)

(0.02

)

Asset and exploration impairments

0.01

Deferred tax asset valuation allowance

—

(56

)

(56

)

(0.06

)

Fair value changes in financial instruments

(528

)

(408

)

(408

)

(0.43

)

Restructuring and transaction costs

246

201

0.21

Gain on equity investment

(201

)

(155

)

(155

)

(0.17

)

Core earnings (Non-GAAP)

1,884

1,479

1.57

Quarter Ended March 31, 2026

Before-tax

After-tax

After NCI

Per Diluted

Total

Earnings (GAAP)

166

120

0.19

Adjustments:

Asset dispositions

—

Asset and exploration impairments

0.01

Fair value changes in financial instruments

644

499

0.81

Restructuring and transaction costs

0.03

Core earnings (Non-GAAP)

832

641

1.04

EBITDAX

Devon believes EBITDAX provides information useful in assessing operating and financial performance across periods. Devon computes EBITDAX as net earnings

before financing costs, net; income tax expense; exploration expenses; depreciation, depletion and amortization; asset disposition gains and losses; non-cash share-based compensation; non-cash valuation changes for derivatives and financial instruments; restructuring and transaction costs; gain on equity investments; accretion on discounted liabilities; and other items not related to normal

operations. EBITDAX as defined by Devon may not be comparable to similarly titled measures used by other companies.

Q2 ‘26

Q1 ‘26

Q4 ‘25

Q3 ‘25

Annualized

Q2 ‘25

Net earnings (GAAP)

1,911

120

562

693

7,644

917

Financing costs, net

125

109

107

109

500

116

Income tax expense

473

185

219

1,892

244

Exploration expenses

Depreciation, depletion and amortization

1,416

904

890

879

5,664

914

Asset dispositions

(25

)

(37

)

(100

)

(307

)

Share-based compensation

132

Derivative & financial instrument non-cash val.

changes

(530

)

644

(59

)

(30

)

(2,120

)

(169

)

Restructuring and transaction costs

246

—

984

Gain on equity investment

(201

)

—

(804

)

—

Accretion on discounted liabilities and other

(12

)

(11

)

EBITDAX (Non-GAAP)

3,478

1,907

1,699

1,860

13,912

1,768

NET DEBT

Devon defines net debt as debt (includes short-term and long-term debt) less cash, cash equivalents and restricted cash. Devon believes that netting these

sources of cash against debt provides a clearer picture of the future demands on cash from Devon to repay debt.

2026

2025

Quarter 2

Quarter 1

Quarter 4

Quarter 3

Total debt (GAAP)

11,388

8,386

8,389

8,391

Less:

Cash, cash equivalents and restricted cash

(1,009

)

(1,815

)

(1,434

)

(1,278

)

Net debt (Non-GAAP)

10,379

6,571

6,955

7,113

NET DEBT-TO-EBITDAX

Devon defines net debt-to-EBITDAX as net debt divided by an annualized EBITDAX

measure. Devon believes this ratio provides information useful to investors in assessing the company’s credit position and debt leverage.

2026

2025

Quarter 2

Quarter 1

Quarter 4

Quarter 3

Net debt (Non-GAAP)

10,379

6,571

6,955

7,113

EBITDAX (Non-GAAP) (1)

8,944

7,234

7,413

7,845

Net

debt-to-EBITDAX (Non-GAAP)

1.2

0.9

(1)

EBITDAX is an annualized measure using a trailing twelve-month calculation.

ADJUSTED FREE CASH FLOW

Devon defines adjusted free cash

flow as total operating cash flow before balance sheet changes adjusted for after-tax restructuring costs and accrued capital expenditures. Devon believes adjusted free cash flow provides a useful measure of

available cash generated by operating activities for other investing and financing activities.

2026

2025

2024

Quarter 2

Quarter 1

Full Year

Total operating cash flow (GAAP)

3,674

1,655

6,711

6,600

Changes in assets and liabilities, net

(924

)

299

(151

)

217

Cash from operations before balance sheet changes

(Non-GAAP)

2,750

1,954

6,560

6,817

Cash restructuring and transaction costs, net of tax

(Non-GAAP) (1)

174

Adjusted operating cash flow (Non-GAAP)

2,924

1,973

6,586

6,826

Capital expenditures (Accrued) (2)

(1,269

)

(848

)

(3,638

)

(3,631

)

Adjusted free cash flow (Non-GAAP)

1,655

1,125

2,948

3,195

(1)

Cash restructuring and transaction costs is net of the associated current tax benefit, after taking into

account permanently non-deductible transaction costs.

(2)

Excludes acquisition capital. Q2 2026, Q1 2026, full-year 2025 and full-year 2024 exclude acquisition costs of

$2,729 million, $151 million, $362 million and $243 million, respectively.

REINVESTMENT RATE

Devon defines reinvestment rate as accrued capital expenditures (excluding acquisitions) divided by adjusted operating cash flow. Adjusted operating cash

flow is our total operating cash flow before balance sheet changes adjusted for after-tax restructuring costs; the reconciliation calculation of adjusted operating cash flow is provided above under

“Adjusted Free Cash Flow.” Devon believes reinvestment rate provides useful information to our investors as an indicator of the capital demands of our business relative to the cash flow generated from normal business operations.

2026

2025

2024

Quarter 2

Quarter 1

Full Year

Capital expenditures (Accrued) (1)

1,269

848

3,638

3,631

Adjusted operating cash flow (Non-GAAP)

2,924

1,973

6,586

6,826

Reinvestment rate (Non-GAAP)

(1)

Excludes acquisition capital. Q2 2026, Q1 2026, full-year 2025 and full-year 2024 exclude acquisition costs of

$2,729 million, $151 million, $362 million and $243 million, respectively.

THIRD-QUARTER AND FULL-YEAR 2026 GUIDANCE

Note:

Devon’s full-year 2026 guidance reflects standalone Devon operations plus Coterra beginning on May 7, 2026.

PRODUCTION GUIDANCE

Quarter 3

Full Year

Low

High

Low

High

Oil (MBbls/d)

550

560

495

505

Natural gas liquids (MBbls/d)

375

385

319

326

Gas (MMcf/d)

4,450

4,500

3,300

3,400

Total oil equivalent (MBoe/d)

1,660

1,690

1,364

1,398

CAPITAL EXPENDITURES GUIDANCE

Quarter 3

Full Year

(in millions)

Low

High

Low

High

Permian

$2,900

Rockies

$875

Eagle Ford

$475

Anadarko

$275

Marcellus

$225

Upstream capital

1,375

1,450

4,675

4,825

Midstream and other capital

125

175

Total capital

1,400

1,500

4,800

5,000

PRICE REALIZATIONS GUIDANCE

Quarter 3

Full Year

Low

High

Low

High

Oil - % of WTI

102

100

NGL - % of WTI

Natural gas - % of Henry Hub

OTHER GUIDANCE ITEMS

Quarter 3

Full Year

($ millions, except Boe and %)

Low

High

Low

High

LOE per BOE

4.60

4.90

5.00

5.20

GP&T per BOE

3.40

3.50

3.00

3.20

Production and property taxes as % of upstream sales

6.5

7.5

6.5

7.5

Exploration expenses

Depreciation, depletion and amortization per BOE

10.75

11.25

11.00

11.50

General and administrative expenses per BOE

1.25

1.35

1.45

Financing costs, net

145

155

495

515

INCOME TAX GUIDANCE

Quarter 3

Full Year

(% of pre-tax earnings)

Low

High

Low

High

Current income tax rate

Effective income tax rate

2026 & 2027 HEDGING POSITIONS

Oil Commodity Hedges

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 2026

10,000

66.13

84,500

56.25

73.11

Q1-Q4 2027

—

38,466

59.04

85.41

Three Way Collars

Period

Volume (Bbls/d)

Weighted

Average Floor

Sold Price

($/Bbl)

Weighted

Average Floor

Purchased Price

($/Bbl)

Weighted

Average Ceiling

Price ($/Bbl)

Q3-Q4 2026

113,000

49.36

59.36

72.36

Q1-Q4 2027

57,397

47.25

57.25

73.14

Oil Basis Swaps

Period

Index

Volume (Bbls/d)

Weighted Average

Differential to WTI

($/Bbl)

Q3-Q4 2026

WTI/NYMEX

83,500

0.95

Q3-Q4 2026

Midland Sweet

46,000

1.10

Q3-Q4 2026

WTI/Brent

8,000

(5.66

)

Q3-Q4 2026

NYMEX Roll

95,000

1.74

Q1-Q4 2027

WTI/NYMEX

32,466

1.04

Q1-Q4 2027

Magellan East Houston

27,000

1.85

Q1-Q4 2027

Midland Sweet

48,000

1.02

Natural Gas Commodity Hedges - Henry Hub

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 2026

247,500

3.80

1,130,000

3.36

5.47

Q1-Q4 2027

—

490,000

3.17

5.33

Natural Gas Basis Swaps

Period

Index

Volume (MMBtu/d)

Weighted Average

Differential to Henry

Hub ($/MMBtu)

Q3-Q4 2026

Houston Ship Channel

50,000

(0.29

)

Q3-Q4 2026

Transco Leidy

250,000

(0.78

)

Q3-Q4 2026

Transco Zone 6 Non-NY

250,000

(0.16

)

Q3-Q4 2026

WAHA

350,000

(1.86

)

Q1-Q4 2027

Transco Leidy

47,500

(0.65

)

Q1-Q4 2027

Transco Zone 6 Non-NY

150,000

0.35

Q1-Q4 2027

WAHA

135,041

(1.30

)

Devon’s oil derivatives settle against the average of the prompt month NYMEX West Texas Intermediate futures price.

Devon’s natural gas derivatives settle against the Inside FERC first of the month Henry Hub index and the end of month NYMEX index. Devon’s NGL derivatives settle against the average of the prompt month OPIS Mont Belvieu, Texas index.

Commodity hedge positions are shown as of June 30, 2026.

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v3.26.1

Document and Entity Information

Aug. 04, 2026

Cover [Abstract]

Entity Registrant Name

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Document Period End Date

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Entity Incorporation State Country Code

Entity File Number

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Entity Tax Identification Number

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Entity Address, Address Line One

THREE MEMORIAL CITY PLAZA

Entity Address, Address Line Two

840 GESSNER ROAD

Entity Address, Address Line Three

SUITE 1400

Entity Address, City or Town

HOUSTON

Entity Address, State or Province

Entity Address, Postal Zip Code

77024

City Area Code

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Local Phone Number

589-4600

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For the EDGAR submission types of Form 8-K: the date of the report, the date of the earliest event reported; for the EDGAR submission types of Form N-1A: the filing date; for all other submission types: the end of the reporting or transition period. The format of the date is YYYY-MM-DD.

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No definition available.

+ Details

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dei_DocumentPeriodEndDate

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xbrli:dateItemType

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Period Type:

duration

- Definition

The type of document being provided (such as 10-K, 10-Q, 485BPOS, etc). The document type is limited to the same value as the supporting SEC submission type, or the word 'Other'.

+ References

No definition available.

+ Details

Name:

dei_DocumentType

Namespace Prefix:

dei_

Data Type:

dei:submissionTypeItemType

Balance Type:

Period Type:

duration

- Definition

Address Line 1 such as Attn, Building Name, Street Name

+ References

No definition available.

+ Details

Name:

dei_EntityAddressAddressLine1

Namespace Prefix:

dei_

Data Type:

xbrli:normalizedStringItemType

Balance Type:

Period Type:

duration

- Definition

Address Line 2 such as Street or Suite number

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No definition available.

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Name:

dei_EntityAddressAddressLine2

Namespace Prefix:

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Data Type:

xbrli:normalizedStringItemType

Balance Type:

Period Type:

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- Definition

Address Line 3 such as an Office Park

+ References

No definition available.

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Name:

dei_EntityAddressAddressLine3

Namespace Prefix:

dei_

Data Type:

xbrli:normalizedStringItemType

Balance Type:

Period Type:

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- Definition

Name of the City or Town

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No definition available.

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Name:

dei_EntityAddressCityOrTown

Namespace Prefix:

dei_

Data Type:

xbrli:normalizedStringItemType

Balance Type:

Period Type:

duration

- Definition

Code for the postal or zip code

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No definition available.

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Name:

dei_EntityAddressPostalZipCode

Namespace Prefix:

dei_

Data Type:

xbrli:normalizedStringItemType

Balance Type:

Period Type:

duration

- Definition

Name of the state or province.

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No definition available.

+ Details

Name:

dei_EntityAddressStateOrProvince

Namespace Prefix:

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Data Type:

dei:stateOrProvinceItemType

Balance Type:

Period Type:

duration

- Definition

A unique 10-digit SEC-issued value to identify entities that have filed disclosures with the SEC. It is commonly abbreviated as CIK.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection b-2

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Name:

dei_EntityCentralIndexKey

Namespace Prefix:

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Data Type:

dei:centralIndexKeyItemType

Balance Type:

Period Type:

duration

- Definition

Indicate if registrant meets the emerging growth company criteria.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection b-2

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Name:

dei_EntityEmergingGrowthCompany

Namespace Prefix:

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Data Type:

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- Definition

Commission file number. The field allows up to 17 characters. The prefix may contain 1-3 digits, the sequence number may contain 1-8 digits, the optional suffix may contain 1-4 characters, and the fields are separated with a hyphen.

+ References

No definition available.

+ Details

Name:

dei_EntityFileNumber

Namespace Prefix:

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Data Type:

dei:fileNumberItemType

Balance Type:

Period Type:

duration

- Definition

Two-character EDGAR code representing the state or country of incorporation.

+ References

No definition available.

+ Details

Name:

dei_EntityIncorporationStateCountryCode

Namespace Prefix:

dei_

Data Type:

dei:edgarStateCountryItemType

Balance Type:

Period Type:

duration

- Definition

The exact name of the entity filing the report as specified in its charter, which is required by forms filed with the SEC.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection b-2

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Name:

dei_EntityRegistrantName

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- Definition

The Tax Identification Number (TIN), also known as an Employer Identification Number (EIN), is a unique 9-digit value assigned by the IRS.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection b-2

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Name:

dei_EntityTaxIdentificationNumber

Namespace Prefix:

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Data Type:

dei:employerIdItemType

Balance Type:

Period Type:

duration

- Definition

Local phone number for entity.

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No definition available.

+ Details

Name:

dei_LocalPhoneNumber

Namespace Prefix:

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Data Type:

xbrli:normalizedStringItemType

Balance Type:

Period Type:

duration

- Definition

Boolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 13e

-Subsection 4c

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Name:

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Namespace Prefix:

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Data Type:

xbrli:booleanItemType

Balance Type:

Period Type:

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- Definition

Boolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 14d

-Subsection 2b

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Name:

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Namespace Prefix:

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Data Type:

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Balance Type:

Period Type:

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- Definition

Title of a 12(b) registered security.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection b

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Name:

dei_Security12bTitle

Namespace Prefix:

dei_

Data Type:

dei:securityTitleItemType

Balance Type:

Period Type:

duration

- Definition

Name of the Exchange on which a security is registered.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection d1-1

+ Details

Name:

dei_SecurityExchangeName

Namespace Prefix:

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Data Type:

dei:edgarExchangeCodeItemType

Balance Type:

Period Type:

duration

- Definition

Boolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as soliciting material pursuant to Rule 14a-12 under the Exchange Act.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 14a

-Subsection 12

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Name:

dei_SolicitingMaterial

Namespace Prefix:

dei_

Data Type:

xbrli:booleanItemType

Balance Type:

Period Type:

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- Definition

Trading symbol of an instrument as listed on an exchange.

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No definition available.

+ Details

Name:

dei_TradingSymbol

Namespace Prefix:

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Data Type:

dei:tradingSymbolItemType

Balance Type:

Period Type:

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- Definition

Boolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as written communications pursuant to Rule 425 under the Securities Act.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Securities Act

-Number 230

-Section 425

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